WO2009023042A1 - Unité combinée modulaire d'entretien de puits - Google Patents

Unité combinée modulaire d'entretien de puits Download PDF

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Publication number
WO2009023042A1
WO2009023042A1 PCT/US2008/005141 US2008005141W WO2009023042A1 WO 2009023042 A1 WO2009023042 A1 WO 2009023042A1 US 2008005141 W US2008005141 W US 2008005141W WO 2009023042 A1 WO2009023042 A1 WO 2009023042A1
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WO
WIPO (PCT)
Prior art keywords
module
well servicing
combination unit
unit according
well
Prior art date
Application number
PCT/US2008/005141
Other languages
English (en)
Inventor
James B. Crawford
Philip Crawford
Lila R. Anderson
Original Assignee
Wise Well Intervention Services, Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Wise Well Intervention Services, Inc. filed Critical Wise Well Intervention Services, Inc.
Priority to CA002684598A priority Critical patent/CA2684598A1/fr
Publication of WO2009023042A1 publication Critical patent/WO2009023042A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/02—Drilling rigs characterised by means for land transport with their own drive, e.g. skid mounting or wheel mounting
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/02—Drilling rigs characterised by means for land transport with their own drive, e.g. skid mounting or wheel mounting
    • E21B7/022—Control of the drilling operation; Hydraulic or pneumatic means for activation or operation

Definitions

  • This invention relates, generally, to the treatment of oil and gas wells using fluids to increase the production capability of the wells, and more specifically, to providing fortreatment of oil and gas wells with a means and apparatus that combines multiple modules- which may include: coiled tubing, nitrogen generation, fluid pumping, blending tanks, wireline inspection, and other modules- into a single unit. Modules may be configured on a truck for onshore use, and un-pinned and configured for Offshore use.
  • the prior art equivalent typically brings as many as five transportation units (tractor- trailers, barges, or boats) to the well to be treated, one having a coil tubing unit; one having either, ajiquid nitrogen tank or a large footprint nitrogen generation unit; one having the nitrogen pumping unit; one high pressure pumping unit for acids and other 5chemicals; and a separate wireline unit.
  • the prior art may have a very large boat or barge with multiple units, each with its own power source. Separate, dedicated power sources for each unit drastically increases the mass and volume that must be transported.
  • Current power packs are horsepower limited, which limits the equipment that each can drive. Conventionally, each of the five units above has its lOown engine. Even with a hydraulic power manifold to drive multiple units from a single engine, the horsepower limits how many can be integrated. The requirement for multiple (or much larger) transportation units increases the transportation costs, time, and personnel required to bring the units to the well and run these services.
  • United States Provisional Patent application 60/699759 teaches a single, relatively 15small, self-powered unit with all of the equipment and accessories for running a nitrogen generation system and pressure pumping chemicals to treat wells.
  • United States Patent 6,230,805 (Vercaemer) teaches a method of hydraulic fracturing in which at least two separate fracturing fluid components are pumped downhole- one of said components being pumped downhole within coiled tubing- but does not teach 0how to accomplish this with a single compact unit in which all equipment is powered by an onsite engine and that also provides for the coil tubing operation and wireline inspection.
  • United Statesi-Patent 6,273,188 teaches a trailer mounted coiled tubing rig- 5United States ⁇ atent '6,702,01 1, also by the present inventors, teaches a combined nitrogen treatment system and coiled tubing system in one tractor/trailer apparatus.
  • a single tractor-trailer unit is provided, in which the tractor itself drives a plurality of hydraulic motors that control the pumps and motors associated with a nitrogen system that is used for injecting nitrogen into a well.
  • a crane unit and a coiled tubing 0injection unit are also provided. Unlike the present invention, no disclosure is made for the provision of wireline inspection, well servicing fluid tanks, mixers, and pumps.
  • the preferred type of nitrogen system is tanks of liquid nitrogen, although an alternative mode is disclosed in which the liquid nitrogen system is replaced with one or more nitrogen generators that gather nitrogen from the earth's atmosphere.
  • the 5nitrogen could be mixed with well servicing fluids provided by the same unit.
  • PCT Application US2004/034521 teaches a three in-one nitrogen treatment system, fluid system, and coiled tubing system in one unit.
  • a single tractor-trailer or marine unit is provided, but unlike the engineless present invention, an onboard engine drives a plurality of hydraulic motors that control the pumps and motors associated with a
  • IOnitrogen system and a fluid system that is used for injecting nitrogen and fluid into a well.
  • a coil tubing system is also provided. The only means disclosed for pumping fluid to the well is through the coil tubing system and no disclosure is made for the injection of well servicing fluids directly into the well, and no fluid blending tank is disclosed. Also, no means for wireline inspection is
  • the off-shore prior art that has the same functionality as the present invention is larger, more expensive, and requires either multiple barges or ships- necessitating additional time and expense for set up and take down of ship to ship plumbing- or a larger, more expensive barge or ship that has a deeper draft and can therefore depart 0from and reach fewer locations.
  • the primary object of this present invention is to provide a small engineless unit that can be placed on a single small barge or ship or a single tractor-trailer or marsh buggy and use an onsite power supply to provide wireline inspection, coil tubing operations, and nitrogen generation and pump a combination of high pressure nitrogen and acids 5or other chemicals into wells.
  • the configuration of the present invention on a marsh buggy could be nearly identical to the configuration on a boat or barge.
  • Combination of multiple units such as a wireline, coil tubing unit, nitrogen generator with fluid pumping and mixing on a single transportation unit and all powered by an external power source through a single onboard custom hydraulic manifold is not known in the 0prior art to the best of the inventor's knowledge.
  • the primary object of the present invention is to provide a modular well servicing unit that can be placed on a single tractor-trailer, amphibious vehicle, or a small barge or ship.
  • a single well servicing combination unit comprising: a hydraulic manifold removablyconnectable to the power-take-off of a power source to drive a plurality of hydraulic pumps and motors that control a plurality of well servicing modules that are removably mounted on said combination unit, said well servicing modules being interconnectable by plumbing.
  • FIG. 1 is a top view diagram of the lay out of a 105 class jack-up boat with a custom hydraulic manifold, wireline inspection module, coil tubing module, crane, mixing tank module, storage tank module, fluid pump with power pack, operator 5console module, and nitrogen generation module, in accordance with an embodiment of the present invention.
  • FIG. 2 is an elevated, block diagram side view of the deck of the boat from FIG. 1 , that shows a nitrogen generation module that is connected to the discharge line at a lOtee, and storage, mixing, and pumping modules for well servicing fluid connected to said discharge line at said tee, in accordance with an embodiment of the present invention.
  • FIG. 3 illustrates, in block diagram, the various systems that are used in accordance 15 with the present invention to treat a well with nitrogen and well servicing fluid, in accordance with an embodiment of the present invention.
  • FIG. 4 is a pictorial view of three nitrogen generator modules, in accordance with an embodiment of the present invention. 20
  • FIG. 5 is a pictorial view of a module using membrane technology to pull gaseous nitrogen out of the atmosphere, in accordance with an embodiment of the present invention.
  • FIG. 6 is a block diagram showing control and power interfaces between a coil tubing deployment module, an injector head module, a well control stack module, and other modules comprising a well intervention servicing unit in accordance with an embodiment of the present invention. 5
  • FIG. 7 shows component layout of a control panel from an Operator Control Module in accordance with an embodiment of the present invention.
  • FIG. 8 shows a block diagram of system and component interfaces of a well servicing lOunit in accordance with an embodiment of the present invention.
  • FIG. 9 shows an embodiment of the present invention configured for land use in accordance with an embodiment of the present invention.
  • FIG. 10 shows a table of interface standards to govern connections between the 15Operator Control Module and other modules within a well intervention servicing unit in accordance with an embodiment of the present invention.
  • the preferred embodiment of the present invention is a well intervention servicing unit, comprising a plurality of modules and components.
  • the interfaces between modules comprising a well intervention servicing unit are standardized so Othat modules that comprise a unit can be disconnected from each other and reconnected to each other and/or other units to comprise an onshore configuration or an offshore configuration of a well intervention servicing unit.
  • the well intervention servicing unit is the entire package of equipment delivered. 5 Example configurations:
  • a well intervention servicing unit Unit comprising a Coil tubing module, a nitrogen module, a truck power pack module, and the hardware for sharing power between these modules, or
  • an OFFSHORE well intervention servicing unit comprising a marine mobile0 power pack module, a coil tubing module, a nitrogen module and hardware for sharing power between these modules.
  • a “Module” can be any of the removably connectable major parts of the well intervention servicing unit Examples comprise but are not limited to: 5 • Coil Tubing Modules, 5 8 • Nitrogen Modules,
  • power pack modules that may comprise a truck engine for onshore or a Marine Mobile power pack for offshore, and • a Wireline Module.
  • a Component is a sub part of a Module. This specification defines components only to the extent necessary for manufacturing or operational flexibility. Examples comprise but are not limited to:
  • the well intervention servicing unit's architecture allows the insertion of different servicing modules -such as a coiled tubing module, a self-generating nitrogen module, and servicing fluid pumps- when ordering future well intervention servicing units without redesign of other Modules (i.e., operator control module, transportation 5modules, and power packs).
  • modules such as a coiled tubing module, a self-generating nitrogen module, and servicing fluid pumps- when ordering future well intervention servicing units without redesign of other Modules (i.e., operator control module, transportation 5modules, and power packs).
  • the well intervention servicing unit's architecture and design documentation allow substitution of major Modules and Components supplied by one manufacturer with Modules and Components meeting the same specifications supplied by another lOmanufacturer to take advantage of shorter lead times.
  • a system integrator approach is enabled by complete modularity. Every piece of well intervention equipment becomes a Module to be "integrated” into a working unit. This gives a user flexibility of design without sacrificing producibility of design (manufacturability — standards) and has direct impact on the depot maintenance program and reduces the number of different
  • FIG. 1 a top view of jack-up boat 10 having either a gasoline engine or a diesel engine is illustrated.
  • a nitrogen generator module 31 also shown in FIG. 4 that extracts nitrogen from the atmosphere to eliminate the need for (and the associated cost of) transporting and filling nitrogen tanks.
  • Removably mounted to boat deck 30 are chemical storage tank 5modules 42 that supply chemicals to blending tank modules 50 where the chemicals
  • the mixed chemicals flow to the well servicing fluid pump module 48.
  • the mixed chemicals may flow through the coil tubing 82, 55 to the well head.
  • Wireline inspection module 52 is removably mounted to deck 30.
  • control cabin module 34 in which the electrical and 5hydraulic modules 36 are controlled by a human operator.
  • the crane module 46 may be welded to the boat or platform deck 30. Components are described in greater detail in the description of FIG. 2 below.
  • FIG. 2 a diagram of a jack-up boat 10 is illustrated.
  • a custom hydraulic manifold 70 that distributes power from a power source 200 to all engineless modules on deck 30- nitrogen air feed module 32, injector module 44, crane module 46, well servicing pump module 48, blending tank module 50, and Wireline module 52.
  • a feed air system 32 that is connected to nitrogen membranes 33. Together, the feed
  • nitrogen generator module 31 (also shown in FIG. 4) that extracts nitrogen from the atmosphere to eliminate the need for (and the associated cost of) transporting and filling nitrogen tanks.
  • nitrogen generator module 31 utilizes a membrane 33 (also shown in detail in FIG. 5) that allows nitrogen-rich air from the earth's atmosphere to 0be continuously fed into the bundle housing. The air reaches the center of the bundle of membrane fibers which, at that point, consists mostly of gaseous nitrogen. The nitrogen collects in the mandrel at the center of the bundle. As the air passes through the bundle of membrane fibers, the oxygen and other fast gases pass through the wall of the membrane fibers as the fast gases go through to be collected at the end. 5Oxygen, water vapor, and the other fast gases are continuously collected and are
  • the nitrogen generator modules 31 of the preferred embodiment accomplish this nitrogen generation with a smaller footprint than any prior art the inventor knows.
  • the nitrogen then flows to the nitrogen booster compressor 38 that then compresses the dry nitrogen to the desired pressure.
  • the nitrogen will then be pumped to the tee 39 where it mixes with a fluidor a fluid mix, such as an acid, and then the resulting mixture enters the discharge line 41.
  • the nitrogen in the discharge line may be either liquid or gas.
  • Removably mounted to boat deck 30 are chemical storage tank modules 42 that supply chemicals to blending tanks 50 where the chemicals are mixed.
  • the mixed chemicals flow first to the centrifugal pump 47 and then to the well servicing fluid pump module 48.
  • Themixed chemicals flow to the tee 39 where the mixed chemicals mix with nitrogen and the resulting mixture flows into the discharge line 41. From the discharge line 41 the resulting mixture can flow directly to the well head or through the coil tubing 55 to the well head.
  • An injector module 44 also described in more detail hereinafter, is situated on the boat deck.
  • a hydraulically driven crane module 46 is also situated onthe boat deck for situating the coiled tubing injector module 44 immediately .above the well being treated.
  • a hose reel module 45 and a coiled tubing reel module 55 are situated on the deck 30.
  • a goose neck module 53 is also situated on the deck 30 adjacent the coiled tubing injector module 44 for feeding the coiled tubing from the reel into the injector.
  • a stripper 54 is located on the lower end of the coiled tubinginjector system 44 for enabling the coiled tubing 55 to be placed into the well being
  • a blow out preventer module 56 is also located on the boat deck to be used in shutting in the well to be treated, if needed.
  • Wireline inspection module 52 is removably mounted to deck 30. Also removably mounted on the deck 30 is a control cabin 34 in which the electrical 36 (not shown) and hydraulic modules 70 are 5controlled by a human operator.
  • Power sources 200 for hydraulic modules 70 may comprise marine mobile power packs removably mounted on marine units, truck power packs, or external power sources.
  • each module and component from FIG. 1 and FIG. 2 can lObe dismounted from any boat or truck/tractor-trailer and removably mounted onto any other boat or truck/tractor-trailer. This feature allows marine units to be converted to land units and vice versa. Modules and components may likewise be removably mounted on amphibious transports and static platforms to comprise amphibious or static units. On a tractor-trailer unit, modules and components may be removably 15mounted on either the tractor or the trailer. The trailer bed of a tractor-trailer unit, the deck of an amphibious transport, and a static platform all function like the boat deck of a marine unit.
  • modules and components of land units may accordingly be converted to marine use.
  • modules and components of marine units may be converted to land use. For example, during and shortly after hurricanes, when marine units cannot be used, modules and
  • 5prime mover 70 is obviously and desirably located on the tractor, and the nitrogen generation system and well servicing fluid system are preferably located on the trailer, most of modules and components can be removably mounted on either the tractor and/or the trailer as desired. It should be noted that all of the modules and components comprising a unit can be located on a combined tractor/trailer configuration that does IOnot require the use of either another tractor or another, separately towed trailer.
  • a single land unit in accordance with an embodiment of the present invention may also comprise multiple trailers pulled by a single truck or tractor. Crane modules may be welded to trailers to form trailer-crane modules.
  • a wireline module in accordance with an embodiment of the present invention may be either a slickline or an electric line.
  • a wireline module in accordance with an embodiment of the present invention may further comprise downhole tools such as any of the following: a torque motor, a down stroke hammer with jars for bidirectional fishing, a flow release spear, an external slip connector, a bit, a mill, a 0solids filter, or a dual flapper blowout prevention valve.
  • the nitrogen air feed module 32 has its output connected into the input of a hydraulic pump 90.
  • the custom hydraulic manifold 70 which may be connected to either a gasoline powered or diesel powered external power source or marine mobile power pack 200, has a return line 74.
  • a hydraulic pump 90 is connected into a hydraulic 5motor 92 that is used to drive the return line 74.
  • a hydraulic pump 95 is connected into a hydraulic motor 98 that is used to drive the chains of the injector module 44 that can either move the coiled tubing into the well being treated or pull the coiled tubing out of the well being treated, as desired,
  • Another hydraulic pump 100 drives a motor 102 to drive the crane 46 illustrated in FIG. 2.
  • Another hydraulic pump 110 drives a motor 112 to power the well servicing pump 48,
  • Another hydraulic pump 116 drives a motor 118 to power the blending tank modules 50, which are illustrated in FIG. 2.
  • Another hydraulic pump 122 drives a motor 124 to power the wireline inspection module 52, which is illustrated in FIG. 2.
  • a custom hydraulic manifold distributes power to each of the modules.
  • Said power source with a power-take-off 200 routed through custom hydraulic manifold 70 drives each of the hydraulic pumps 90, 95, 100, 1 10, 116 and 122 as shown by the line 105.
  • 25122 are preferably driven by one or more belts that can be used with clutch pulleys as
  • the compressor module 108 is also driven by the custom hydraulic manifold 70 via the drive line 105 to bring the nitrogen down to its desired temperature.
  • a power-take-off on the vessel rig, platform, work boat, tug boat, or jack up barge
  • that power source 200 with over 1000 horsepoweravailable, can drive more machines than a less powerful onboard source could.
  • the preferred embodiment of the present invention can operate with a separate land or marine external power source. As long as the preferred embodiment of the present invention can avail itself of an adequate power source it can do all of the following well servicing, including but not limited to: - Completions,
  • One advantage of an embodiment of the present invention is that it makes it possible to do with one unit and a single power source what previously required multiple separate powered units- a wireline inspection unit, a coiled tubing unit, a liquid nitrogen tank transport means, a powered unit with a high pressure pumping systemfor other chemicals and acids, and a unit with a nitrogen pumping means. Because an embodiment of the present invention allows one unit to do what once required several powered units connected together with the requisite hoses and plumbing, the time and expense of plumbing rig-up is avoided. Disconnecting and stowing all of the plumbing after completion is also avoided, saving additional time and labor.
  • the preferred embodiment of the present invention can do the same job with one unit in one day.
  • the present invention saves the trouble and expense of transporting multiple separate power sources to the site, each of which takes up over sixty square feet of deck space, allowing this combined unit to besmaller and cheaper than any prior art equivalent.
  • 1 coil tubing unit is a 175 class boat, yet an embodiment of the present invention with an integrated coil tubing module along with four other integrated modules can be placed on a single 105 class boat.
  • the deck load of the prior art equivalent would be about 150,000 pounds, yet an embodiment of the present invention has a deck load of 5only about 50,000 pounds, allowing operations in shallower water.
  • the danger of transporting liquid nitrogen, which is an explosion hazard, is also avoided. Hazards associated with running plumbing and hoses from boat to boat are also avoided, and fewer personnel are required.
  • the preferred embodiment of the present invention has a smaller footprint and lighter weight than any functional lOequivalent.
  • An embodiment of the present invention comprising a nitrogen generation module is advantageous in remote locations where liquid nitrogen is rare and expensive, or extremely difficult to transport to the well head.
  • an embodiment of the present invention is well suited for off shore use. Because of a marine unit embodiment's small footprint, an embodiment of the present invention allows replacement of large, expensive vessels with much smaller and cheaper barges or ships that have shallower drafts. 0It should be noted that while the embodiment described so far is powered by a prime mover such as a marine mobile power pack, the invention can also be removably mounted on and use the engine of a truck power pack and is equally suited for on shore use. An embodiment of the present invention may be trailered on land, to replace as many as five separate units and realize similar time and cost savings. 5 5 1
  • Another embodiment of the present invention comprises an onshore-offshore convertible well intervention servicing unit Combination Coiled Tubing and Cryogenic Nitrogen Unit with the option of a Self-Generating Nitrogen Module, though nitrogen tank modules can also serve as a nitrogen source. 5
  • An embodiment of the present invention configured for land use could comprise: a Truck Power Pack and a crane-trailer module loaded, having modules removably mounted thereon such as: an Operator Control Module, Coiled Tubing Deployment Module, Injector Head Module, Well Control Stack and Blow Out Preventer Module, lOand Nitrogen Generation Module to and from well servicing sites. At well servicing sites, the Truck Power Pack will power the servicing equipment.
  • modules removably mounted thereon such as: an Operator Control Module, Coiled Tubing Deployment Module, Injector Head Module, Well Control Stack and Blow Out Preventer Module, lOand Nitrogen Generation Module to and from well servicing sites.
  • the Truck Power Pack will power the servicing equipment.
  • An advantage of the present invention is that customer-furnished equipment can be provided to be integrated into the Well Intervention Unit, allowing a high degree of 15customization and cost savings. Changes to the unit configuration can be made much later in the manufacturing/assembly process, or even after the unit is in use in the field.
  • This well intervention servicing unit can be deployed for both on-shore and off-shore jobs:
  • the onshore subset of this well intervention servicing unit is a truck power pack that tows all servicing modules removably mounted on a crane trailer to the job site and then powers the servicing equipment on the job site.
  • An offshore embodiment of the present invention can comprise a well 5intervention servicing unit comprising an operator control module and servicing modules removed from a unit's onshore crane trailer module plus a marine mobile power pack. These modules can be transported by truck to a port and then transported by boat to an offshore oil platform. On the offshore oil platform, a marine mobile power pack module can supply all power required for the well intervention servicing lOunit in accordance with an embodiment of the present invention.
  • the marine mobile power pack can be used as a backup or substitute for a well intervention unit's power source.
  • the well intervention servicing unit can be augmented by an independently-powered fluid pump (customer-furnished) to deliver servicing fluid or nitrified servicing fluid into the well.
  • the well intervention servicing unit provides fluid 0pumping from its Marine Mobile Power Pack to deliver servicing fluid or nitrified servicing fluid into the well.
  • the well intervention servicing unit can be reconfigured for different well-servicing functions at the maintenance depot level.
  • the cryogenic liquid nitrogen module can be replaced by or augmented by a fluid servicing pump without modifying the 5 operator control module.
  • a single set of interface standards should be universal throughout all of the well intervention servicing units.
  • These interface standards govern connections between the OperatorControl Module and other modules within the well intervention servicing unit.
  • An example of such a set of interface standards is shown in the table from FIG. 10.
  • a well intervention servicing unit in accordance with an embodiment of the present invention will preferably provide nitrogen at a discharge pressure ranging from 0- 7500 pounds per square inch gauge and at an operator-controllable flow rate ranging from 0-850 standard cubic feet per minute, while maintaining the dischargetemperature at 10°F above ambient.
  • the well intervention servicing unit will preferably transfer servicing fluid from an independently-powered, customer-furnished source tothe well via 2-inch pipe with 1502 Hammer unions compatible with well-servicing fluids.
  • Offshore configuration the well intervention servicing unit will preferably transfer servicing fluid from an independently-powered, customer-furnished source tothe well via 2-inch pipe with 1502 Hammer unions compatible with well-servicing fluids.
  • the well intervention servicing unit will preferably 5pressurize and transfer servicing fluid from a customer-furnished source to the well via the coiled tubing at an operator-controllable flow rate ranging from 0 to 50 gallons per minute and a pressure ranging from 0-5000 pounds per square inch gauge.
  • the Truck Power Pack will tow the well intervention servicing unit trailer (comprising for example: a crane trailer loaded with an Operator Control Module, Coiled Tubing Deployment Module, and Nitrogen Module) to and from well servicing sites.
  • the well intervention servicing unit trailer comprising for example: a crane trailer loaded with an Operator Control Module, Coiled Tubing Deployment Module, and Nitrogen Module
  • a well servicing unit configured for land use in accordance with an embodiment of the present invention should preferably be capable of travel over a wide range of roads, paved and unpaved, between well-servicing jobs.
  • a well intervention servicing unit in accordance with an embodiment of the present invention should be configured for transportation to minimize need for special permits in 0onshore and offshore configurations.
  • the well intervention servicing unit in accordance with an embodiment of the present invention can operate beyond its transportation envelope with an operator-extended crane and other extensions such as coolers or open 5ventilation doors.
  • a well intervention servicing unit, module, or component in accordance with an embodiment of the present invention may be shipped overseas.
  • 5WeIl intervention servicing modules in accordance with an embodiment of the present invention can be installed onto the Onshore Transport Trailer Module with cranes or forklifts.
  • 1OA well intervention servicing unit in accordance with an embodiment of the present invention can provide self-contained onshore transportation for the onshore configuration.
  • An embodiment of the onshore configuration typically comprises all modules except the offshore marine mobile power pack, transportation skid kit, and hose basket with offshore hose bundle.
  • a well intervention servicing unit in accordance with an embodiment of the present invention in an onshore transportation configuration should preferably have a total height less than 13 feet, 6 inches.
  • a well intervention servicing unit in accordance with an embodiment of the present invention shall weigh no more than
  • Total unit weight (wet) shall preferably not exceed 140,000 pounds.
  • a well intervention servicing unit in accordance with an embodiment of the present invention in an onshore transportation configuration should preferably have a total width of less than 8 feet, 6 inches.
  • a well intervention servicing unit in accordance with an embodiment of the present invention in an onshore transportation configuration should preferably have a total length of less than 64 feet. 5
  • a marine mobile power pack module in accordance with an embodiment of the present invention should preferably be transportable onshore on trucks.
  • OA well intervention servicing unit in accordance with an embodiment of the present invention should preferably comprise skids for offshore transportation configuration weighing no more than 18,500 pounds each, except for the coil tubing drum loaded with coil tubing in its transportation skid.
  • Coil tubing reels may, in accordance with an embodiment of the present invention, range in size from 48 inches to 168 inches in 5diameter.
  • a well intervention servicing unit in accordance with an embodiment of the present invention in the offshore configuration should preferably weigh less than 85,000 pounds including one full cryogenic nitrogen storage vessel and 10,000 feet of 1 1 A"0coil tubing.
  • a well intervention servicing unit in accordance with an embodiment of the present5invention should preferably be designed so that the following modules and components can be removed from its onshore transportation trailer for separate transport to an offshore site: operator control module coil tubing deployment module
  • a realistic goal for onshore to offshore conversion is completion in 8 hours lOusing a three-person operations crew and the following equipment: customer-furnished forklift, customer-furnished crane,
  • Transportation Skid Kit included with the a well intervention servicing unit in accordance with an embodiment of the present invention
  • 15- Hose Reel Skid included with the well intervention servicing unit in accordance with an embodiment of the present invention .
  • Availability is defined as the well intervention servicing unit being ready for transit lObetween well-servicing sites and for performing well-servicing activities. Increasing availability of units minimizes maintenance down time and increases utilization rate.
  • a well intervention servicing unit in accordance with an embodiment of the present 0invention should preferably provide well services for 12 hours without refueling.
  • An advantage of a unit in accordance with an embodiment of the present invention is that failure of certain modules or components will not render the entire unit nonfunctional, since modules and components can be replaced in the shop or in the 5field.
  • a well intervention servicing unit in accordance with an embodiment of the present invention should preferably incorporate provision for a modules or componentscoming later consistent with the interface requirement,also known as hardware "scars", for the post-deployment addition of additional modules or components. Namely, for a well servicing fluid pump integrated into the onshore configuration, an operator control module fluid pump control should be provided.
  • a well intervention servicing unit in accordance with an embodiment of the present invention may comprise the following modules: One (1) Operator Control Module One ( 1 ) Truck Power Pack
  • An Operator Control Module in accordance with an embodiment of the present invention allows central control and operation of multiple well-serving functions from a single power sourceand control point. Mated with the appropriate power sources and ancillary equipment packages, this module monitors and controls function of other modules such as: Coiled Tubing Deployment, Cryogenic Nitrogen, and Fluid Pumping Operations (if installed).
  • the Operator Control Module should preferably provide:
  • the Operator Control Module should preferably be a skid-mounted module with a crash frame; forklift guide tubes and a four point sling lift attachment points. Lifting 5slings are customer-furnished equipment.
  • the Operator Control Module should preferably e 96" long x 96" wide with height to allow 13 '6" height clearance when loaded on a 48" tall truck trailer.
  • the Operator Control Module should preferably weigh 15,50001bs or less.
  • the Operator Control Module should preferably operate in the offshore well servicing environment.
  • the Operator Control Module should preferably operate in the onshore well servicing environment.
  • a control module in accordance with an embodiment of the present invention will preferably comprise a single console, to control the entire unit as shown for example in FIG. 7.
  • the left one third of the example console shown in FIG. 7 is dedicated to Nitrogen pumping and Truck Tractor control functions.
  • the right hand two thirds is occupied by the Coiled Tubing Functions controls.
  • the FIG. 7 diagram indicates the location of the various control valves, gauges, and other devices. A brief description of the 0related functions follows.
  • Truck Tractor related controls are designated as 701 through 712, then moving right Nitrogen Controls are 713 through 731 and, finally, Coiled Tubing Controls are 732 5through 775.
  • Truck Tractor Controls are designated as 701 through 712, then moving right Nitrogen Controls are 713 through 731 and, finally, Coiled Tubing Controls are 732 5through 775.
  • shut down relay in the tractor's electronic vehiclecontrol module. To restart / reset simply push back into the down / open position.
  • 702 is a proportional air regulator valve which operates the air throttle cylinder on the engine fuel injector pump. Pushing forward increases engine speed, pulling back reduces it.
  • 703 is an electronic tachometer that picks up engine speed from the alternator.
  • 704 is an electronic temperature gauge monitoring engine water temperature. This is a switch gauge, meaning at a specific temperature setting a switch is closed and an alarm function is activated.
  • 706 is an electronic temperature gauge which indicates the temperature of the working hydraulic fluid in the reservoir on the Truck Power Pack. This is the fluid at rest, prior to beginning its working cycle. Temperatures of 165-180 0 F are normal,higher temperatures are to be avoided. Temperatures above 200 0 F are likely to do rapid damage to motor and pump seals.
  • 707 is an electronic temperature indicator that monitors the lube oil temperature in the Nitrogen injection pump crankcase or "Warm End”.
  • 708 is an electronic temperature indicator that monitors the crankcase oil in thetruck auxiliary transmission.
  • 709 is a red flashing warning lamp tied to the alarm functions of other switchgages.
  • this flasher When any of the switchgages reach their alarm setpoint, this flasher will light, it is not resetable, it will continue to flash until the alarm condition is corrected.
  • “710” is an electrical toggle switch which control instrument panel back lighting.
  • “711” is the stainless steel enclosure wherein all electrical components are housed.
  • “712” is an electrical rocker switch that increases “accel” or decreases “decel” engine speed on the truck engine. This is redundant to the cruise control switch on the dashboard inside the truck cab. This control is a remote operation of the truck cruise control system.
  • “713” is an electronic temperature indicator monitoring the water glycol mixture as it enters the nitrogen evaporator pot. This temperature is normally very close to the hydraulic return manifold temperature. The water glycol mixture enters the heatexchanger at the return manifold specifically to be heated and capture waste hydraulic heat.
  • “714" is the electronic temperature gauge that tracks the water glycol mixture as it leaves the evaporator pot. Typically this reading closely relates to the temperature of the discharged nitrogen gas. "715" is a pressure indicator reading the hydraulic pressure applied to the liquid nitrogen boost pump drive motor.
  • “716” is a hydraulic relief valve employed to directly control the hydraulic pressure applied to the liquid nitrogen boost pump drive motor.
  • “717” is the nitrogen tank discharge (vaporizer inlet) pressure gauge (10,000 psi)
  • “718” is the boost pump discharge pressure gauge.
  • “719” is a pressure gauge used to monitor the hydraulic pressure on the liquid nitrogen warm end drive motor.
  • 720 is a hydraulic relief valve used to pilot control a larger relief valve under the console, which regulates the hydraulic pressure supplied to the warm end drive motor.
  • 721 is a master system air pressure gauge.
  • “723” is a 3-way ball valve to direct air pressure to a HP autoclave valve actuator to open or close a stream of charged liquid for tempering the discharge gas temperature.
  • "724" is a 3-way ball valve to air operate a HP autoclave valve actuator to either pump to the vaporizer or high pressure by-pass the charged liquid back to the liquid nitrogen tank.
  • "725" is a 4- way crossover valve to provide air to an actuated ball valve to either direct boost pump output, to cold ends, or back to the liquid nitrogen tank, a boostpump prime line.
  • “726” is a 4- way crossover valve to open and close the actuator on the boost pump to atmosphere prime line.
  • “727” is a pressure gauge used to monitor the hydraulic pressure being supplied to an auxiliary heat build system.
  • “728” is a relief valve used to remote/pilot operate a larger relief valve under the console, to build-up additional waste heat for nitrogen vaporization.
  • “729” is an electronic rate totalizer and meter that counts warm end rotations to determine gaseous nitrogen discharge rate and track cumulative totals.
  • 3 "731" is a spare 3-way ball valve.
  • 732 is a pressure gauge used to monitor wellhead pressures.
  • 733 is a pressure gauge used to monitor circulating pressures.
  • 734" is a pressure gauge used to monitor the status of the injector head brake circuit.
  • Parking braking on the injector heads are mechanically spring applied, and hydraulically released, therefore zero pressure indicates brakes are set, and 1000+ pounds per square inch guage indicates brakes are released.
  • "735" is a 3-way ball valve used to either bleed-off or supply hydraulic pressure to the injector head brake circuit.
  • “736” is a pressure gauge that reads hydraulic pressure in the injector head motor range selector circuit.
  • the 2-speed motors on the injector head default to a full displacement/low speed mode. Therefore zero pressure indicates low speed selection,and 300-400 pounds per square inch gage indicates high range is selected.
  • 737 is a 3-way ball valve used to either bleed-off or supply hydraulic pressure to the injector head 2-speed shift circuit.
  • “738” is a pressure gauge indicating the hydraulic pressure being supplied to the injector head main drive motor circuit.
  • “739” is a relief valve used to pilot/remote operate another larger relief valve mounted on the main coil tubing system distribution manifold under the console. This relief valve regulates the pressure on the injector head drive motor circuit.
  • “740” is a hydraulic joystick used to pilot operates a larger directional valve mounted on the main coil tubing system distribution manifold under the console. This valve in turn directs the hydraulic flow to either run into or out of the wellbore/injector head
  • “741” is a directional valve used to override the level- wind assembly on the front of the working reel.
  • “742” is a directional valve which raises or lowers the level-wind assembly to insure the operator can visually watch the wraps on the reel, and clearly see the counterhead.
  • “743” is a dual reading pressure gauge calibrated to measure Coiled Tubing pipe weight both pulling downward, pipe heavy, and pushing upward, pipe light, on the inner injector head frame.
  • “744" is a pressure gauge which indicates the charge pressure on the injector head chain oiler reservoir.
  • "745" is a needle valve employed to control flow of oil from the injector head oiler reservoir to the injector head chains.
  • “746” is a pneumatic regulator used to provide and regulate the air over oil charge onthe chain oiler reservoir.
  • “747” is a 3-way ball valve used to either bleed-off or supply hydraulic pressure to the work reel brake circuit.
  • “748” is a pressure gauge monitoring the pressure on the work reel brake system. A pressure of 300-400 pounds per square inch guage releases the brake.
  • “749” is a relief valve which pilot/remote operates another larger relief valve located under the console. This valve control the pressure supplied to the working reel drive circuit to either spool up tubing coming out of the hole, or to maintain tension on the reel playing out into the hole to prevent bird-nesting the coil tubing reel.
  • “750” is a directional valve to either place the working reel in: neutral, forward or reverse. The normal operating mode is for the reel to remain in reverse; only rarely will the reel purposely be driven forward to push coiled tubing off of the drum.
  • blow out preventer accumulator drain is a pressure indicator that shows the system charge pressure on the blow out 5preventersystem. Normally 2,500-3,000 pounds per square inch gage is charged on the system. If lower pressures are present it is generally a result of the blow out preventer accumulator drain having been left open.
  • “754" is a pressure gauge which indicates the pressure on the reel drive/back pressure system. 15"755" is the pneumatic regulator that drives the air over hydraulic pump used to pressurize the stripper/pack-off circuit.
  • 0"758 is a directional valve used to operate the cylinder build into the stripper/packoff to either retract of pack-off the coil tubing.
  • “759” is a reducing valve used to adjust the pressure provided to the skate cylinders on the injector head.
  • 760 is a needle valve provided to drain/bleed-off pressure on the injector skates and 5tensioner cylinders.
  • "761” is a reducing valve used to adjust the pressure provided to the outside chain tension cylinders on the injector head.
  • “762” is a ball valve used to direct and control hydraulic pressure to the outside chain tension cylinders on the injector head.
  • 5 “763” is a pressure gauge indicating the pressure on the outside chain tension cylinders.
  • 765" is a ball valve used to direct and control the pressure in the top skate cylinders.
  • “766” is a ball valve used to direct and control the pressure in the mid skate cylinders lOon the injector head.
  • “768” is a pressure gauge indicating the pressure on the bottom skate cylinders.
  • “769” is a ball valve used to direct and control the pressure in the bottom skate cylinders.
  • 15”770” is a needle valve used as a dampener to stabilize the pipe heavy readings on the weight indicator.
  • 771 is a needle valve used as a dampener to stabilize the readings of the pipe light conditions on the weight indicator.
  • blow out preventer control valves Pulling up actuates blow out preventer control valves.
  • "775" is pressure reducing valve to further control injector head speed in "high” range.
  • a control module in accordance with an embodiment of the present invention 5comprises a control console module may comprise any of the following controls and indicators:
  • Blow out preventer control valves should preferably be labeled from left to right “Blinds", “Cutters”, “Slips”, “Pipe”, “Aux Pipe” and “Blind Shears”. Blow out preventer's to lOhave an emergency back-up circuit from an air or hand operated in cabin pump.
  • Injector Weight Indicator mounted in center of Panel Upper section. Indicator 20 should preferably read 60,0001b pipe heavy and 15,0001b pipe light.
  • Gresen (Munson-Tyson Type) Control Valve for Injection speed and direction, with Cartridge valve for fine control of injector speed. (Auto-driller arrangement)
  • Power Pack Engine remote instrumentation Package to include, Tachometer, Coolant Temperature.
  • Nitrogen Boost Pump liquid nitrogen discharge pressure gauge 150 pounds per square inch
  • Nitrogen tank discharge (vaporizer inlet) pressure gauge 10,000 pounds per square inch
  • debooster or remote sender to protect operators from cryogenic nitrogen exposure in case of gauge or gauge plumbing failure.
  • the hydraulic controls should preferably be rated for operation at 3000 pounds per 15 square inch working pressure. Hydraulic Distribution
  • the hydraulic distribution component of the operator control module should preferably include: 0
  • the hoses should preferably be labeled at each end with bands imprinted with customer-specified text and by numbered stainless steel washers.
  • the electrical distribution component of the operator control module should preferably distribute 120 volts alternating current from the electric generator to the listed components at no more than listed current: 15- the control cabin air conditioning component (10.0 amps) the control cabin lighting (2.0 amps)
  • the electrical distribution component of the operator control module should preferably distribute 120 volts alternating current from an offshore platform supply to 0the listed components at no more than listed current: the control cabin air conditioning component (10.0 amps) the control cabin lighting (2.0 amps)
  • the electrical distribution component should preferably transform 120 volts alternating current to 12 volts direct current and distribute 12 volts direct current tomonitoring instrumentation.
  • the Water-Glycol Distribution component should preferably distribute a water and glycol mix from the power pack to the cryogenic liquid nitrogen modules via the hydraulics heat exchanger.
  • the operator control module shall:
  • An over-the-road truck tractor provides onshore transportation and onshore power tothe hydraulic systems for all Coiled Tubing and Nitrogen Modules.
  • the truck power pack should preferably tow the trailer containing the crane and well- servicing modules to onshore well servicing sites and maintenance locations. At the well-servicing site, the truck power pack should preferably provide hydraulic power to concurrently operate the coil tubing and nitrogen modules at their maximum capabilities described in the section above on functional and performance requirements. 5
  • the truck power pack should preferably operate in the onshore well servicing environment.
  • the truck power pack comprises a Freightliner 515-hp Detroit Diesel series 60, 14.0L lOtractor with 10-speed transmission plus "wet kit” comprising: an auxiliary transmission, a pair of power take offs, a hydraulic reservoir, a glycol reservoir, fluid coolers, hydraulic pumps, and various hoses, fittings, and control valves. Its features include:
  • One (1) double-vane hydraulic pump with one (1) circuit dedicated to the coiled tubing reel hydraulics distribution, and one (1) circuit dedicated to Blow out 25preventer and safety control modules hydraulic distribution.
  • One (1) glycol reservoir and expansion chamber One (1) glycol reservoir and expansion chamber.
  • the OnShore Transport Trailer with Crane should preferably operate in the onshore well servicing environment.
  • a 48ft long single drop-deck triple-axle trailer provides the transportation and work platform for all the well servicing equipment and a hydraulic pedestal crane.
  • Upper deck should preferably be plate
  • lower section should preferablybe bare frame rails. - 8' width
  • Injector head and well control stack equipment mount should preferably be within the crane's operating envelope. As shown in FIGS. 8 and 9, the injector may be operated 5 continuously at the intersection of any speed and pull combination as long as the intersection remains on or to the left and below of the lOOhp continuous output curve.
  • Injector head mount should preferably position the HydraRig 635 injector head so that the COIL TUBING can remain stabbed during transport between well servicing sites.
  • Mounting brackets and setups should preferably secure one 1800-gallon cryogenic liquid nitrogen tank (tank itself is described in nitrogen module specification).
  • Crane Assembly 5A hydraulically-operated pedestal crane (such as: National Crane Model 638, 18 ton Pedestal Crane) should preferably be installed on the crane trailer.
  • Crane Capacities 0 36,000 lbs. maximum
  • Rotation 5270 degree non-continuous by means of planetary gear, hydraulic drive unit, and swing stops.
  • Anti-Two Block 15 Explosion-proof system that helps prevent cable damage by sensing position of winch cable and attachments with respect to sheave case.
  • the crane must fold up and fit in the space provided on the crane trailer during transport.
  • Reel Pivot A reel pivot cylinder that will pivot to either side of the unit will be installed on the unit.
  • a unit in accordance with an embodiment of the present invention can deploy coiled tubing using various configurations. For example see the following combinations of coil tubing deployment modules and injector heads can all function within an lOembodiment of the present invention:
  • Example one comprises a Modified HPT 122 inch coiled tubing Reel Assembly and a
  • HydraRig 635 injector head
  • Example two comprises a Modified HPT 122" coiled tubing Reel Assembly and a 15HydraRig 635 injector head.
  • Example three comprises a 102" coiled tubing Reel Assembly and a HydraRig 635 injector head.
  • Example four comprises a 102" coiled tubing Reel Assembly and a HydraRig 635 injector head. 20In the 122" configurations the unit in accordance with an embodiment of the present invention can: spool 1-3/4" diameter coiled tubing @ 2500 pounds per square inch gauge operating pressure. provide coiled tubing storage capacity for 1"- 2-1/2" Coiled Tubing . 25- provide coiled tubing capacity by volume of :
  • the unit in accordance with an embodiment of the present invention can: spool 1-1/2" diameter x 0.125" wall thickness coiled tubing @ 2500 pounds per square inch gauge operating pressure. provide coiled tubing storage capacity for 1"- V ⁇ " Coiled Tubing. - provide coiled tubing capacity by volume of:
  • this embodiment of the well intervention servicing unit coiled tubing length is limited by weight carrying capacity, not volume. Depending upon the wall thickness string length capacities will vary.
  • This embodiment of the well intervention servicing unit supplies hydraulic fluid to an injector at an operator-controllable rate ranging from 0-85 gallons per minute (inclusive) and at an operator-controllable pressure ranging from 0- 3000 pounds per square inch gauge (inclusive).
  • Cryogenic Liquid Nitrogen Module The Cryogenic Liquid Nitrogen Module should preferably output up to 1,500 standard cubic feet per minute gaseous nitrogen at 10,000 pounds per square inch gauge. However, note that overall integrated unit nitrogen capacities are below this peak dueto horsepower limitations.
  • the Cryogenic Liquid Nitrogen Module should preferably meet these output requirements in the onshore well servicing environment.
  • the cryogenic liquid nitrogen module has two major components: - the cryogenic liquid nitrogen storage vessel the nitrogen pump and vaporization component Cryogenic Liquid Nitrogen Storage Vessel
  • a unit in accordance with an embodiment of the present invention may comprise aCryogenic Liquid Nitrogen Storage Vessel module comprising a double layer vacuum insulated pressure vessel.
  • This tank should preferably be provided with fill, suction vent, and pressure building manifolds and valves.
  • the vessel capacity should preferably be approximately 1800 liquid gallons. This vessel will be removably attached to the upper deck on a land transport trailer:
  • a Cryogenic Liquid Nitrogen Pump and Vaporization Component in accordance with an embodiment of the present invention should preferably draw cryogenic liquid 5nitrogen from the Cryogenic Liquid Nitrogen Storage vessel and force it through the vaporizer to produce gaseous nitrogen.
  • the Cryogenic Liquid Nitrogen Pump and Vaporization Component in accordance with an embodiment of the present invention should preferably meet its output lOrequirements in the offshore well servicing environment.
  • a Cryogenic Liquid Nitrogen Pump and Vaporization Component in accordance with an embodiment of the present invention may, for example comprise:
  • cryogenic centrifugal boost pump with mated high speed hydraulic motor to draw cryogenic liquid nitrogen from the storage vessel and pump it at low pressure (less than lOOpounds per square inch gauge) to a triplex injection pump.
  • Triplex IWiCTB 100 type Cryogenic Nitrogen Positive displacement Pump with mated bent axis hydraulic motor, to develop pressure necessary to overcome the 0resi stance to the fluid through the vaporizer.
  • This component should preferably be packaged separate from other systems and the cryogenic liquid nitrogen storage vessel. 5
  • a Cryogenic Liquid Nitrogen Pump and Vaporization Component in accordance with an embodiment of the present invention should interface with customer-furnished offshore cryogenic liquid nitrogen storage vessels without modification.
  • a Marine Mobile Power Pack in accordance with an embodiment of the present invention should preferably provide hydraulic power to concurrently operate the coil tubing and nitrogen modules at their maximum capabilities.
  • a Marine Mobile Power Pack in accordance with an embodiment of the present invention should meet its power output requirement in the offshore well servicing environment.
  • 5A Marine Mobile Power Pack in accordance with an embodiment of the present invention should preferably be skid-mounted and comprise a crash frame, forklift guide tubes and a 4-point lift attachment for lifting slings, and one fall protection harness tie off point incorporated into its crash frame.
  • OA Marine Mobile Power Pack in accordance with an embodiment of the present invention should preferably be no larger than 126 "long x 96" wide x 102" high including the structural skid to allow 13 '6" height clearance when loaded on a 48" tall truck trailer.
  • a Marine Mobile Power Pack in accordance with an embodiment of the present invention should preferably weigh no more than 18,5001bs maximum wet.
  • a Marine Mobile Power Pack in accordance with an embodiment of the presentinvention may, for example, have the following features:
  • Caterpillar matched heavy duty solder dripped radiator has onboard systems for shutdown in over- temperature and low oil pressure situations. Engine also has overspeed auto-shutdown protection and spark arrester exhaust.
  • Air Operated fuel shutdown system and air operated emergency shutdown (air shut-off).
  • Emergency Kill system is failsafe (air signal to run, absent signal shutdown) type.
  • Axial Piston high pressure open-loop pump for coiled tubing injector drive Axial Piston high pressure open-loop pump for Nitrogen System drive. Double Vane pump for tubing reel and blow out preventer functions. - Single Gear pump for water/glycol circulation.
  • Hydraulic Pump relief valves are piloted to a series of dump valves at a system start panel.
  • Crash Frame provides an integrated access ladder to skid top
  • An Electric Generator provides electric power for distribution by the operator control module in onshore applications.
  • An electric generator in accordance with an embodiment of the present invention may, for example:
  • the Electric Generator should preferably meet these requirements in the onshore well servicing environment.
  • a Coil Tubing Reel Carry Skid is used for transport of a Coil Tubing Reel Drum when the drum is removed from unit.
  • a Coil Tubing Reel Carry Skid in accordance with an embodiment of the present lOinvention should preferably hold the Coil Tubing Reel Drum in axle-horizontal position during: onshore transport offshore boat transport
  • Coil Tubing Reel Carry Skid should comprise 15forklift and crane sling provisions for moving between ground, truck, and boat in loaded and unloaded configurations, and one fall protection harness tie off point incorporated into its crash frame.
  • a Coil Tubing Component Carry Skid is used for transport of injector head, well control stack, and coiled tubing-specific tools when removed from a unit's onshore transportation trailer in accordance with an embodiment of the present invention.
  • a Coil Tubing Component Carry Skid in accordance with an embodiment of the present invention should preferably hold the injector head, well control stack, and coiled tubing-specific tools during: onshore transport from onshore-to-offshore conversion location to dock 5- offshore boat transport
  • a Coil Tubing Component Carry Skid in accordance with an embodiment of the present invention should preferably have provisions for moving between ground, truck, and boat in loaded and unloaded configurations.
  • a hose reel skid When the well servicing unit is converted to offshore use, a hose reel skid will provide the hydraulic fluid distribution between the modules in accordance with an embodiment of the present invention .
  • the onshore hydraulic fluid distribution can 15remain on the crane trailer.
  • a Hose Reel Skid in accordance with an embodiment of the present invention should preferably carry all the well servicing unit's interconnecting hoses needed for offshore use. 0
  • a Hose Reel Skid in accordance with an embodiment of the present invention should preferably protect the well servicing unit's interconnecting hoses from damage during transport from onshore to offshore.
  • a Hose Reel Skid in accordance with an embodiment of the present invention should preferably have provisions for moving between ground, truck, and boat in loaded and unloaded configurations.
  • Control Module in 35 -foot lengths.
  • Hoses necessary to connect the Operator Control Module to the coiled tubing reel in 35-foot lengths. Hoses should preferably be labeled at each end with bands imprinted with text and by numbered stainless steel washers.
  • a Hose Reel Skid in accordance with an embodiment of the present invention should preferably include 3 hose reels: - One reel for operator control module to injector head power hoses
  • One reel for injector head control hoses One reel for blow out preventer control hoses
  • the Hose Reel Skid should preferably include a hose rack for the marine mobile power pack-to-operator control module hoses.

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Abstract

La présente invention concerne, de manière générale, le traitement de puits de pétrole et de gaz à l'aide de fluides destinés à augmenter la capacité de production des puits et, plus spécifiquement, le traitement de puits de pétrole et de gaz à l'aide d'un moyen et d'un appareil combinant de multiples modules dans une seule unité, par exemple un tube d'intervention enroulé, un module de génération d'hydrogène, un module de pompage de fluide, des réservoirs de mélange, un module de contrôle des câbles et d'autres modules. Les modules peuvent être conçus sur une plateforme pour une utilisation sur terre et désarticulés pour une utilisation en mer.
PCT/US2008/005141 2007-04-19 2008-04-21 Unité combinée modulaire d'entretien de puits WO2009023042A1 (fr)

Priority Applications (1)

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CA002684598A CA2684598A1 (fr) 2007-04-19 2008-04-21 Unite combinee modulaire d'entretien de puits

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US92543107P 2007-04-19 2007-04-19
US60/925,431 2007-04-19
US92651707P 2007-04-29 2007-04-29
US60/926,517 2007-04-29

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