WO2009105032A1 - Navire destiné à stocker des fluides et procédé de confinement de fluides à bord d'un navire - Google Patents

Navire destiné à stocker des fluides et procédé de confinement de fluides à bord d'un navire Download PDF

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Publication number
WO2009105032A1
WO2009105032A1 PCT/SG2008/000059 SG2008000059W WO2009105032A1 WO 2009105032 A1 WO2009105032 A1 WO 2009105032A1 SG 2008000059 W SG2008000059 W SG 2008000059W WO 2009105032 A1 WO2009105032 A1 WO 2009105032A1
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WIPO (PCT)
Prior art keywords
vessel
tanks
spillage
fluids
enclosure
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PCT/SG2008/000059
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English (en)
Inventor
Brian Phillip Dobson
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Individual
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Individual
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Priority to PCT/SG2008/000059 priority Critical patent/WO2009105032A1/fr
Publication of WO2009105032A1 publication Critical patent/WO2009105032A1/fr
Anticipated expiration legal-status Critical
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Classifications

    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B25/00—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby
    • B63B25/02—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby for bulk goods
    • B63B25/08—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby for bulk goods fluid
    • B63B25/082—Arrangements for minimizing pollution by accidents
    • 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
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/001—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor specially adapted for underwater drilling
    • 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
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/01—Arrangements for handling drilling fluids or cuttings outside the borehole, e.g. mud boxes

Definitions

  • the present invention relates broadly to a vessel for storing fluids and to a method for containing fluids onboard a vessel.
  • the vessel can also be configured for mixing fluids and treating fluids and treating drilling waste. 10
  • drilling rigs such as oil rigs
  • different chemically formulated materials are 15 typically used on the- rigs for different drilling operations.
  • drill cuttings ⁇ contaminated with drilling fluids are typically generated during drilling operations.
  • the drilling fluids materials are typically prepared on land by mixing different chemicals according to different recipes. After obtaining the different materials on land, the materials are typically transported to the rigs using boats or ships. Due to typical substantial transporting distances, the materials can be easily contaminated typically with water leaking into the fluids from pumping operations.
  • drilling waste cuttings generated on the rigs through drilling operations are typically partially treated on the rigs, e.g. by solids control equipment, and then either discharged overboard into the environment or discharged into small transport
  • a vessel for storing fluids comprising one or more storage tanks for storing fluids; an enclosure formed around the storage tanks; one or more spillage tanks in fluid communication with the enclosure; and wherein when the fluids are released into the enclosure, the fluids are drained into the spillage tanks under gravitational force.
  • the enclosure may comprise containment wall sections, wherein one or more of the containment wall sections function as a side railing of the vessel.
  • One of the containment wall sections may separate a living quarters of the vessel from the enclosure for containing the fluid within the enclosure and away from the living quarters.
  • One of the containment wall sections may function as a bow spread wall.
  • the vessel may further comprise one or more drainage inlets disposed in the enclosure for providing the fluid communication between the spillage tanks and the enclosure.
  • the vessel may further comprise a first pipe system for providing active fluid communication between the spillage tanks and the storage tanks; and a pump for returning the drained fluids from the spillage tanks against gravitational force to the storage tanks via the first pipe system.
  • the vessel may further comprise a pump room external to the spillage tanks wherein the pump is disposed in the pump room; a water chest disposed in the pump room, the water chest for providing fluid communication with the pump for pumping water onto the vessel.
  • the vessel may further comprise a second pipe system for connecting the pump to an airconditioning system such that water pumped onto the vessel is circulated to the airconditioning system via the second pipe system.
  • the vessel may further comprise a third pipe system for providing fluid -communication between the spillage tanks; and a submersible pump provided in one of the spillage tanks for pumping the drained fluids between the spillage tanks via the third pipe system.
  • the spillage tanks may be incorporated in a hull section of the vessel.
  • the storage tanks may be disposed on a deck level of the vessel.
  • the vessel may further comprise a fluid discharge pipe system interconnecting the storage tanks; and a fluid suction pipe system interconnecting the storage tanks; wherein the vessel is configured for treating fluids and drilling waste and for mixing fluids using the interconnected storage tanks.
  • a method for containing fluids onboard a vessel for storing fluids comprising providing one or more storage tanks onboard the vessel for storing fluids; forming an enclosure around the storage tanks; providing one or more spillage tanks in fluid communication with the enclosure; and wherein when the fluids are released into the enclosure, containing of the fluids into the spillage tanks occurs under gravitational force.
  • the enclosure may comprise containment wall sections, wherein one or more of the containment wall sections function as a side railing of the vessel.
  • the method may further comprise providing the fluid communication between the spillage tanks and the enclosure using one or more drainage inlets disposed in the enclosure.
  • the method may further comprise providing active fluid communication between the spillage tanks and the storage tanks using a first pipe system; and returning the drained fluids from the spillage tanks against gravitational force to the storage tanks via the first pipe system using a pump.
  • the method may further comprise providing a pump room external to the spillage tanks wherein the pump is disposed in the pump room; providing fluid communication with the pump using providing a water chest disposed in the pump room for pumping water onto the vessel.
  • the method may further comprise connecting the pump to an airconditioning system using a second pipe system such that water pumped onto the vessel is circulated to the airconditioning system via the second pipe system.
  • the method may further comprise providing fluid communication between the spillage tanks using a third pipe system; and pumping the drained fluids between the spillage tanks via the third pipe system using a submersible pump disposed in one of the spillage tanks.
  • the spillage tanks may be incorporated in a hull section of the vessel.
  • the storage tanks may be disposed on a deck level of the vessel.
  • the method may further comprise interconnecting the storage tanks using a fluid discharge pipe system; and interconnecting the storage tanks using a fluid suction pipe system; for treating fluids and drilling waste and for mixing fluids using the interconnected storage tanks.
  • Figure 1 is a schematic side view diagram of a vessel in an example embodiment.
  • Figure 2(a) is a schematic top view diagram of the vessel.
  • Figure 2(b) is a schematic enlarged view of section A of Figure 2(a).
  • Figure 2(c) is a schematic enlarged view of section B of Figure 2(a).
  • Figure 3(a) is a schematic top-down view of a hull section of the vessel.
  • Figure 3(b) is a schematic enlarged view of section C of Figure 3(a).
  • Figure 3(c) is a schematic isolated view of section D of Figure 3(a).
  • Figure 4 is a schematic isolated top view of a section of a deck section of the vessel.
  • Figure 5 is schematic view along an A-A line with reference to Figure 4.
  • Figure 6 is schematic view along a B-B line with reference to Figure 4.
  • Figure 7(a) is a schematic top view showing a fluids discharge pipe system of deck tanks.
  • Figure 7(b) is a schematic isometric view of the fluids discharge pipe system.
  • Figure 8(a) is a schematic top view showing a fluids suction pipe system of the deck tanks.
  • Figure 8(b) is a schematic isometric view of the fluids suction pipe system.
  • Figure 9 is a schematic flowchart illustrating a method for draining fluids onboard a vessel in an example embodiment.
  • Figure 1 is a schematic side view diagram of a vessel 102 in an example embodiment.
  • the vessel can be a towed vessel such as a barge or a self-powered vessel.
  • the vessel 102 comprises a deck section 104 and a hull section 106.
  • the deck section 104. is disposed on the hull section 106.
  • the deck section 104 comprises a plurality of mixing compartments e.g. 108, 110, living quarters 112 and containment wall sections, herein referred to as walls e.g. 114, 116, 118, 120, 122.
  • the walls may be made of, but not limited to, steel etc. In the example embodiment, one or more of the walls e.g.
  • 114, 116, 118, 120, 122 can function as a side railing of the vessel.
  • the gates can be mechanically operated to open to discharge e.g. rain water on the deck section 104 and to close to prevent sea water from entering the deck section 104 e.g. if the weather is rough. If a spill of stored/mixing fluids is detected from the mixing compartments e.g. 108, 110, these gates can be sealed closed further by e.g. fastening of wing nuts provided on each of these gates to prevent spilled material from leaking outside the walls 114, 116, 118, 120, 122.
  • FIG. 2(a) is a schematic top view diagram of the vessel 102.
  • Figure 2(b) is a schematic enlarged view of section A of Figure 2(a).
  • Figure 2(c) is a schematic enlarged view of section B of Figure 2(a).
  • Each mixing compartment e.g. 108, 110 comprises a plurality of storage or deck tanks e.g. 202, 204.
  • the deck tanks e.g. 202, 204 are disposed on a deck level of the vessel 102.
  • the deck tanks e.g. 202, 204 are connected using a plurality of mixing line pipes and mixing valves e.g. 206. Chemicals stored in the deck tanks e.g.
  • Each deck tank e.g. 202, 204 can be mixed by operating the mixing valves e.g. 206.
  • Each deck tank e.g. 202, 204 further comprises one or more agitators e.g. 208 for facilitating the mixing.
  • One or more diesel pumps e.g. 210, 212 may be used to pump chemicals into or out of the deck tanks -e.g. 202, 204 for e.g. mixing operations.
  • a crane 214 is provided on the deck section 104 for moving or loading/unloading material, equipment etc. on the vessel 102.
  • the vessel 102 can be anchored about 2 to 4 kilometers from a drilling rig to provide e.g. different drilling fluids for different drilling operations.
  • the drilling fluids are mixed onboard the vessel 102 and transported to the drilling rig by supply vessels.
  • the walls 114, 116, 118 and 122 enclose the mixing compartments e.g. 108, 110 in a first enclosure 216.
  • the walls 114, 116, 118 and 120 enclose the living quarters 112 in a second enclosure 218.
  • the wall 118 separates the living quarters 112 of the vessel 102 from the first enclosure 216 such that fluids released into the first enclosure 216 is contained within the first enclosure 216 and away from the living quarters 112.
  • the vessel 102 further comprises drainage inlets 220, 222 in the first enclosure 216.
  • the walls 114, 116, 118 and 120 are each at least about 1.2 meters or about 4 feet in height.
  • the wall 122 is bow spread to at least about
  • the first enclosure 216 can contain fluid spillage from the deck tanks e.g. 202, 204, ie. preventing fluid spillage from leaking outside the walls 114, 116, 118 and 122 forming the first enclosure 216.
  • the wall 122 is bow spread such that it can be used for towing operations and for e.g. coping with rough weather.
  • Figure 3(a) is a schematic top-down view of the hull section 106.
  • Figure 3(b) is a schematic enlarged view of section C of Figure 3(a).
  • Figure 3(c) is a schematic isolated view of section D of Figure 3(a).
  • the hull section 106 comprises a plurality of void tanks e.g. 302, 304, a pump room 306, a main spillage containment tank 308 and a starboard spillage containment tank 310.
  • the void tanks e.g. 302, 304 can provide buoyancy to the vessel 102.
  • the main spillage containment tank 308 is located at aft port quarter and the starboard spillage containment tank 310 is located amidships starboard to provide stability to the vessel 102.
  • the main spillage containment tank 308 and the starboard spillage containment tank 310 are connected (not shown) to each other via a pipe system.
  • the pipe system comprises flexible high pressure rubber hoses. Fluids in the starboard spillage containment tank 310 can be pumped into the main spillage containment tank 308 via the pipe system using a submersible internal pump 316.
  • the pump room 306 comprises a pump 312 and is connected to the main spillage containment tank 308.
  • the pump room 306 further comprises a water or sea chest 314 connectable to the pump 312.
  • the sea chest 314 is secured and is used for pumping sea water onto the vessel 102.
  • the main spillage containment tank 308 and the starboard spillage containment tank 310 can each contain about 350 m 3 or about 5000 barrels (bbls) of fluid. It will be appreciated that the capacities of the main spillage containment tank 308 and the starboard spillage containment tank 310 can be configured such that the main spillage containment tank 308 and the starboard spillage containment tank 310 are capable of containing the total storage capacity of the deck tanks e.g. 202, 204 ( Figure 2).
  • Figure 4 is a schematic isolated top view of a section 228 ( Figure 2) of the deck section 104.
  • the drainage inlets 220, 222 are located such that materials released in the first enclosure 216 from e.g. the deck tanks e.g. 202, 204 ( Figure 2) can be easily drained or channeled to the main spillage containment tank 308 ( Figure 3) and the starboard spillage containment tank 310 ( Figure 3) respectively.
  • Fluid communication is provided between the first enclosure 216 and the main spillage containment tank 308 ( Figure 3) and the starboard spillage containment tank 310 ( Figure 3).
  • A-A line (see numerals 402, 404) is provided in Figure 5.
  • a view along a B-B line (see numerals 406, 408) is provided in Figure 6.
  • FIG 5 is schematic view along the A-A line with reference to Figure 4.
  • the drainage inlet 220 is connected in fluid communication with the main spillage containment tank 308 using a pipe 502.
  • the drainage inlet 220 is covered using a grizzly screen.
  • the grizzly screen is constructed from stainless steel and can have apertures of about 5 to 10 mm in diameter to ensure that clogging does not occur at the grizzly screen.
  • the pipe 502 can be e.g. made of a 12" piping.
  • a stainless steel grating may be provided to cover an inlet opening of the pipe 502.
  • active fluid communication between the main spillage containment tank 308 and the deck tanks e.g. 202, 204 ( Figure 2) is provided using another pipe system and via the pump 312 ( Figure 3).
  • the pipe system can comprise e.g. a 6" pipe and/or high pressure rubber hoses.
  • the pump 312 ( Figure 3) can be used to transfer spillage material contained in the main spillage containment tank 308 to the deck tanks e.g. 202, 204 ( Figure 2) via the pipe system against gravitational force.
  • FIG. 6 is schematic view along the B-B line with reference to Figure 4.
  • the drainage inlet 222 is connected in fluid communication with the starboard spillage containment tank 310 using a pipe -602 and a valve 604.
  • the drainage inlet 222 is covered using a grizzly screen.
  • the inlet opening of the pipe 602 is covered with a stainless steel grating.
  • the grizzly screen is constructed from stainless steel and can have apertures of about 5 to 10 mm in diameter to ensure that clogging does not occur at the grizzly screen.
  • the pipe 602 is inverted after the valve 604 such that spillage materials can be discharged directly from the pipe 602 into the starboard spillage containment tank 310.
  • spillage containment and management can be provided onboard the vessel 102.
  • a spillage can occur when a mixing valve e.g. 206 breaks and the pressure in one or more deck tanks e.g. 202, 204 ( Figure 2) equalize, thus releasing stored chemicals into the first enclosure 216. Since the first enclosure 216 is enclosed within the walls 114, 116, 118 and 122, the chemicals are funneled or channeled to flow into the main spillage containment tank 308 ( Figure 3) and the starboard spillage containment tank 310 ( Figure 3) via the drainage inlets 220, 222 respectively.
  • the example embodiment does not require a separate drainage pump for spillage containment and management.
  • the main spillage containment tank 308 ( Figure 3) and the starboard spillage containment tank 310 ( Figure 3) are capable of containing the total storage capacity of the deck tanks e.g. 202, 204.
  • any spillage of materials or chemicals is contained and prevented from leaking from the vessel 102.
  • the main spillage containment tank 308 and the starboard spillage containment tank 310 can function as temporary storage for spillage materials until there are available deck tanks e.g. 202, 204 ( Figure 2) to contain or remove the spillage materials from the vessel 102.
  • the pump room 306 further comprises an access stairs 318 and water tight doors (not shown).
  • the access stairs 318 can allow access to the pump room 306 from the second enclosure 218 ( Figure 2) via e.g. an access stairs 224 ( Figure 2).
  • the pump room 306 can also provide a number of other functions.
  • the pump room 306 can provide a continuous supply of cooling water for air- conditioning systems in e.g. the living quarters 112 ( Figure 2) by using the pump 312 to draw sea water via the sea chest 314 and via another pipe system.
  • the pump room 306 can also circulate cooling water to electric generators or electric generating engines used e.g. in the living quarters 112 ( Figure 2) by using the pump 312 to draw sea water via the sea chest 314.
  • An oily-water separator (not shown) can be installed in the pump room 306 to provide environmentally acceptable or "clean" cooling water for the circulating cooling water.
  • the vessel 102 further comprises a High "G” force solids removal centrifuge apparatus 226.
  • the centrifuge apparatus 226 can be used for treatment/conditioning and/or removal from the drilling fluids e.g. of solid materials formed in the drilling fluids during drilling operations to obtain suitable drilling fluids.
  • the centrifuge apparatus 226 is connected by suitable pipes (not shown) into the deck tanks e.g. 202, 204 such that mixing of materials to obtain a particular drilling fluid can be carried out using a to and return flow of materials via the centrifuge apparatus 226.
  • the high "G” force centrifuge apparatus 226 can maintain the properties and weight of the drilling fluids without having to perform such operations on the oil rigs themselves. • ⁇ ⁇
  • FIG 7(a) is a schematic top view showing a fluids discharge pipe system of the deck tanks.
  • Figure 7(b) is a schematic isometric view of the fluids discharge pipe system.
  • Each deck tank e.g. 202, 204 comprises a discharge valve V1 e.g. 702, 704.
  • the discharge valve V1 e.g. 702, 704 is connected and opened for fluids to be discharged into the respective deck tank e.g. 202, 204 using the diesel pumps e.g. 210, 212.
  • Figure 8(a) is a schematic top view showing a fluids suction pipe system of the deck tanks.
  • Figure 8(b) is a schematic isometric view of the fluids suction pipe system.
  • Each deck tank e.g. 202, 204 further comprises a suction valve V2 e.g. 802, 804.
  • the suction valve V2 e.g. 802, 804 is connected and opened for fluids to be "sucked" from the respective deck tank e.g. 202, 204 using the diesel pumps e.g. 210, 212.
  • a deck tank A can be used for mixing of a particular volume of a fluid with specified properties. After mixing is achieved, the fluid can be stored in another deck tank B for transfer to an oil rig that requires the fluid.
  • deck tanks e.g. 202, 204 each comprises a solid steel chequer plate roof so that water proofing may be provided for drilling fluids. It will be appreciated by a person skilled in the art that rain water can have adverse effects on drilling fluids.
  • the crane 214 can be of about 165 feet with a rotational radius of about 150 feet so that the crane can lift loads from e.g. ends of the vessel 102 and supply boats.
  • a forklift of about 13 feet may also be provided on the deck section 104 for facilitating lifting of loads.
  • a contaminated drilling waste treatment process such as a Total Waste Management Alliance (TWMA) Hammer mill or a Thermal Desorbtion Unit (TDU) unit
  • TWMA Total Waste Management Alliance
  • TDU Thermal Desorbtion Unit
  • Contaminated drilling waste can be received from oil rigs or feeder barges and stored in one or more of the deck tanks.
  • the waste can. be transmitted to a process unit from the deck tanks using e.g. a slurry pump.
  • Oily water skimmers can be provided in these deck tanks for separation of any water contaminates.
  • a base oil portion can be stored in one or more of the deck tanks of the vessel.
  • the deck tanks for storing such base oil portions can be modified to accommodate such materials.
  • Water from the processed waste can be channelled to a sewage treatment tank (not shown) for further treatment for controlled discharge or transferred to a contaminated water storage tank (not shown) for chemical treatment.
  • the remainder of the processed decontaminated drilling waste can be released into the environment (subject to regulations) or returned to shore e.g. for use for other purposes.
  • Figure 9 is schematic flowchart 900 illustrating a method for containing fluids onboard a vessel in an example embodiment.
  • one or more storage tanks onboard the vessel for storing fluids are provided.
  • an enclosure around the storage tanks is formed.
  • one or more spillage tanks in fluid communication with the enclosure are provided.
  • the vessel 102 can be used for mixing, storing, centrifuging, conditioning and treating drilling fluids etc. Since treatment and mixing of drilling fluids on the vessel 102 is carried out "off-line" from actual drilling rig operations, rig time delays in waiting on tank cleaning on drilling units can be eliminated. Contamination of drilling fluids such as water can also be prevented when transferring the drilling fluids to transporting vessels and marine bases. Since handling of drilling fluids by drilling rigs can be reduced (ie. by up to 90% for handling carried out on the vessel 102), only day to day maintenance would be required on drilling units. In addition, storage of drilling fluids on the vessel 102 after utilization on wells, during rig moves and prior to being utilized again (ie.
  • the vessel 102 can significantly eliminate the travelling distance from drilling rigs to a supply base since it can be located at a closer distance to the oil rig. This can reduce supply vessel costs and travel frequency.
  • other marine supply vessels can be freed to utilize their deck load capacity for other supplies and thus, can improve provide logistical support for drilling rigs (e.g. even providing temporary storage of drilling items).
  • the above described example embodiment can also provide, beside drilling fluids, mixing, treating, reconditioning and storage of Water Base Mud (WBM) and Synthetic Base Mud (SBM) 1 Drill in Fluids WBM and SBM, and completion brines.
  • WBM Water Base Mud
  • SBM Synthetic Base Mud
  • IADC International Association of Drilling Contractors
  • Non-dispersed systems include spud muds, natural muds and other lightly treated systems that are generally used for shallow wells or top-hole drilling. Thinners and dispersants are not added to disperse drill solids and clay particles.
  • Dispersed systems are provided where at greater depths, where higher densities are required, or where hole conditions may be problematic, muds are often dispersed, typically with lignosulfonates, lignites or tannins. These and similar products are effective deflocculants and filtrate reducers. Potassium-containing chemicals are frequently used to provide greater shale inhibition. Specialized chemicals are also added to adjust or maintain specific mud properties.
  • Calcium treated systems are provided where divalent cations, such as calcium and magnesium, when added to a freshwater drilling mud, inhibit formation clay and shale swelling. High levels of soluble calcium are used to control sloughing shale and hole enlargement, and to prevent formation damage. Hydrated lime (calcium hydroxide), gypsum (calcium sulfate) and calcium chloride are principal ingredients of calcium systems. Gyp systems usually have a pH of 9.5 to 10.5 and an excess gyp concentration of 2 to 4 Ib/bbl (600 to 1 ,200 mg/l calcium).
  • Lime systems typically have either excess lime concentration of 1 to 2 Ib/bbl and a pH of 11.0 to 12.0 for a low lime system, or excess lime concentration of 5 to 15 Ib/bbl for a high lime system. Specialized products are added to control individual mud properties. Calcium-treated muds resist salt and anhydrite contamination but are susceptible to gelation and solidification at high temperatures. Polymer systems are provided where muds incorporating generally long-chain, high-molecular-weight polymers are utilized to either encapsulate drill solids to prevent dispersion and coat shales for inhibition, or for increasing viscosity and reducing fluid loss. Various polymers are available for these purposes, including acrylamide, cellulose and natural gum-based products.
  • inhibiting salts such as KCI or NaCI
  • KCI or NaCI are used to provide greater shale stability.
  • These systems normally contain a minimum amount of bentonite and may be sensitive to divalent cations, such as calcium and magnesium.
  • Most polymers have temperature limits below 300 0 F, but under certain conditions, may be used in wells with appreciably higher BHTs.
  • Low solids systems are provided where listings include systems in which the amount (volume) and type of solids are controlled. Total solids should not range higher than about 6% to 10% by volume. Clay solids should be some 3% or less and exhibit a ratio of drilled solids to bentonite of less than 2:1. Low-solids systems typically use polymer additive as a viscosifier or bentonite extender and are non-dispersed. One primary advantage of low-solids systems is that they significantly improve drilling penetration rate.
  • Saltwater systems are provided. Saturated salt systems have a chloride concentration near 190,000 mg/l (saturated) and are used to drill salt formations. Saltwater systems have a chloride content of 10,000 to 190,000 mg/l. The lower levels are usually referred to as brackish or seawater systems. Saltwater muds are usually prepared from brackish, seawater or produced-water sources. Muds are prepared from fresh or brine water and dry sodium chloride (or other salts, such as potassium chloride used for shale inhibition), which are added to achieve desired salinity. Various specialty products, such as attapulgite, CMC, starch and others, are used to increase viscosity for hole-cleaning properties and to reduce fluid loss.
  • Oil-based muds are provided where oil-based systems are used for a variety of applications, where fluid stability and inhibition are necessary, such as high-temperature wells, deep holes, and where sticking and hole stabilization are problems. They comprise two types of systems. Invert emulsion muds are water-in-oil emulsions, typically with calcium chloride brine as the emulsified phase and oil as the continuous phase. They may contain as much as 50% brine in the liquid phase. Relaxed, invert emulsion muds are a "relaxed" emulsion, and have lower electrical stabilities and higher fluid-loss values. Concentration of additives and brine content/salinity are varied to control Theological, filtration and emulsion stability.
  • Oil-based muds are formulated with only oil as the liquid phase and are often used as coring fluids. Although these systems pick up water from the formation, no additional water or brine is added. All oil systems require higher additional gelling agents for viscosity.
  • Specialized oil-based mud additives include: emulsifiers and wetting agents (commonly fatty acids and amine derivatives) for viscosity; high-molecular-weight soaps; surfactants; amine treated organic materials; organo clays and lime for alkalinity.
  • Synthetic muds systems are provided. Synthetic fluids are designed to mirror oil- based mud performance, with less environmental hazards. Primary synthetic fluids include paraffins, iso-paraffins, esters, ethers, poly alpha olefins and isomerized alpha olefins. Synthetic based drilling fluids use a variety of different "Base Oils”.
  • Air, mist, foam and/or gas systems are provided.
  • Four basic operations are included in this category. These include dry air drilling, which involves injecting dry air or gas into the wellbore at rates capable of achieving annular velocities that will remove cuttings; mist drilling, which involves injecting a foaming agent into the air stream that mixes with produced water and coats the cuttings to prevent mud , rings, allowing drill solids to be removed; foam uses surfactants and possibly clays or polymers to form a high carrying-capacity foam; and aerated fluids rely on mud with injected air (which reduces hydrostatic head) to remove drilled solids from the wellbore.
  • dry air drilling which involves injecting dry air or gas into the wellbore at rates capable of achieving annular velocities that will remove cuttings
  • mist drilling which involves injecting a foaming agent into the air stream that mixes with produced water and coats the cuttings to prevent mud , rings, allowing drill solids to be removed
  • foam uses surfactants
  • additives are listed below. These are generally accepted by the IADC Subcommittee on Drilling Fluids. Additives are typically transported dry, e.g. in sacks, and prepalletized to oil rigs or vessels for further/additional treatment of already formulated or mixed drilling fluid systems. Some additives have multiple uses, and for those a primary and two secondary function categories are listed.
  • Alkalinity, pH control additives are provided which include products used to control the degree of acidity or alkalinity of a fluid include lime, caustic soda, soda ash and bicarbonate of soda, as well as other common acids and bases.
  • Bactericides are provided which include products used to prevent bacterial degradation of natural organic additives, such as starch and xanthan gum.
  • Calcium reducers are provided which include soda ash, bicarbonate of soda, caustic soda and certain polyphosphates used to reduce calcium in seawater, treat cement contamination, and overcome contaminating effects of anhydrite and gypsum, both forms of calcium sulfates.
  • Corrosion inhibitors are provided where pH control, along with an appropriate corrosion inhibitor, is used to control corrosion, neutralize hazardous acid gases and prevent scale in drilling fluids.
  • Common corrosion inhibitors are amine- or phosphate- based products, as well as other specially formulated chemicals.
  • Defoamers are provided which include products designed to reduce foaming action, particularly in brackish and saturated saltwater muds.
  • Emulsifiers include products that create a heterogeneous mixture (emulsion) of two insoluble liquids. They include fatty acids and amine-based chemicals for oil-based muds and detergents; soaps; organic acids; and water-based surfactants for water-based muds. Products may be anionic (negatively charged), non- ionic (neutral) or cationic (positively charged) chemicals, depending on the application.
  • Filtrate reducers include filtrate, or fluid loss reducers - such as bentonite clays, lignite, CMC (sodium carboxymethylcellulose), polyacrylate and pregelatinized starch - that serve to decrease fluid loss, a measure of the tendency of the drilling fluid's liquid phase to pass through the filter cake into the formation.
  • filtrate, or fluid loss reducers - such as bentonite clays, lignite, CMC (sodium carboxymethylcellulose), polyacrylate and pregelatinized starch - that serve to decrease fluid loss, a measure of the tendency of the drilling fluid's liquid phase to pass through the filter cake into the formation.
  • Flocculants are provided to increase viscosity for improved hole cleaning, to increase bentonite yield and to clarify or de-water low-solids fluids.
  • Salt or brine
  • hydrated lime gypsum
  • soda ash bicarbonate of soda
  • sodium tetraphosphate sodium tetraphosphate
  • acrylamide-based polymers may be used. They cause colloidal particles in suspension to group into bunches or "floes," causing solids to settle out.
  • Foaming agents are provided which include chemicals that also act as surfactants (surface active agents) to foam in the presence of water. These foamers permit air or gas drilling through water-bearing formations.
  • Lost circulation materials are provided to plug the zone of loss back in the formation, away from the borehole face, so that subsequent operations will not result in additional drilling fluids losses.
  • Lubricants are provided which include products designed to reduce a drilling fluid's coefficient of friction, which decreases torque and drag.
  • Various oils, synthetic liquids, graphite, surfactants, glycols and glycerin, as well as other chemicals, are used for this purpose.
  • Pipe-freeing agents include products consisting of detergents, soaps, oils, surfactants and other chemicals. These agents are spotted in an area of suspected pipe stickage to reduce friction and increase lubricity, thereby freeing stuck pipes.
  • Shale control inhibitors include sources of soluble calcium and potassium, as well as inorganic salts and organic compounds, that provide shale control by reducing shale hydration. These products are used to prevent excessive wellbore enlargement and heaving or caving while drilling water-sensitive shales.
  • Surface active agents include surfactants, as they are called, that reduce interfacial tension between contacting surfaces (water/oil, water/solid, water/air, etc.). These may be emulsifiers, de-emulsifiers, wetting agents, flocculants or deflocculants, depending on the surfaces involved.
  • Temperature stability agents are provided which include products that increase rheological and filtration stability of drilling fluids exposed to high temperatures and those that continue to perform their intended purpose under these conditions.
  • Various chemicals are used, including acrylic polymers, sulfonated polymers and copolymers, as well as lignite, lignosulfonate and tannin-based additives.
  • Thinners, dispersants are provided which include chemicals that modify the relationship between viscosity and percentage of solids in a drilling mud. They may be used, further, to reduce gel strength, increase a fluid's "pumpability," etc.
  • Tannins (quebracho) various polyphosphates, lignite and lignosulfonate materials function as thinners, or as dispersants. Principal purpose of a thinner is to function as a deflocculant to reduce attraction (flocculation) of clay particles, which produces high viscosity and gel strengths.
  • Viscosifiers are provided which include Bentonite, CMC, attapulgite clays and polymers that are used to increase viscosity for better hole cleaning and suspension of solids.
  • Weighting materials are provided which include Barite, iron oxides, calcium carbonates and similar products possessing high specific gravity that are used to control formation pressures, check formation caving and facilitate pulling dry pipe.

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  • Engineering & Computer Science (AREA)
  • Health & Medical Sciences (AREA)
  • Environmental & Geological Engineering (AREA)
  • Public Health (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • Ocean & Marine Engineering (AREA)
  • Treatment Of Sludge (AREA)

Abstract

L'invention concerne un navire destiné à stocker des fluides et un procédé de confinement de fluides à bord d'un navire. Le navire comporte un ou plusieurs réservoirs de stockage destinés à stocker des fluides ; une enceinte formée autour des réservoirs de stockage ; un ou plusieurs réservoirs de déversement en communication fluide avec l'enceinte ; et quand les fluides sont libérés dans l'enceinte, les fluides sont évacués dans les réservoirs de déversement sous l'effet d’une force de gravitation.
PCT/SG2008/000059 2008-02-19 2008-02-19 Navire destiné à stocker des fluides et procédé de confinement de fluides à bord d'un navire Ceased WO2009105032A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
PCT/SG2008/000059 WO2009105032A1 (fr) 2008-02-19 2008-02-19 Navire destiné à stocker des fluides et procédé de confinement de fluides à bord d'un navire

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/SG2008/000059 WO2009105032A1 (fr) 2008-02-19 2008-02-19 Navire destiné à stocker des fluides et procédé de confinement de fluides à bord d'un navire

Publications (1)

Publication Number Publication Date
WO2009105032A1 true WO2009105032A1 (fr) 2009-08-27

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PCT/SG2008/000059 Ceased WO2009105032A1 (fr) 2008-02-19 2008-02-19 Navire destiné à stocker des fluides et procédé de confinement de fluides à bord d'un navire

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WO (1) WO2009105032A1 (fr)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN103693165A (zh) * 2013-12-20 2014-04-02 舟山市蓬莱船舶修造有限公司 船体中化学品独立货舱的制造方法
CN121088323A (zh) * 2025-10-16 2025-12-09 浙江省电力建设有限公司 海水基环保泥浆的智能配比与动态净化循环系统

Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2329509A (en) * 1940-12-06 1943-09-14 Harry G Atwood Process for fermented cereal beverages
US3547301A (en) * 1968-02-21 1970-12-15 Conch Ocean Ltd Tanker for liquefied gases
US4079689A (en) * 1975-07-10 1978-03-21 Sener, Tecnica Industrial Y Naval, S.A. Partial secondary barriers for self-supporting, axi-symmetrical tanks on board vessels
US4245748A (en) * 1977-10-20 1981-01-20 Moss Rosenberg Verft A/S Leak protection system on a tank for storing or transporting liquefied gas
WO1992005069A1 (fr) * 1990-09-21 1992-04-02 George Paraskevopoulos Navire-citerne
WO1998022335A1 (fr) * 1996-11-22 1998-05-28 Ship Based System As Vaisseau polyvalent
US6345672B1 (en) * 1994-02-17 2002-02-12 Gary Dietzen Method and apparatus for handling and disposal of oil and gas well drill cuttings
US6745856B2 (en) * 2002-07-17 2004-06-08 M-I, L.L.C. Methods and apparatus for disposing of deleterious materials from a well

Patent Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2329509A (en) * 1940-12-06 1943-09-14 Harry G Atwood Process for fermented cereal beverages
US3547301A (en) * 1968-02-21 1970-12-15 Conch Ocean Ltd Tanker for liquefied gases
US4079689A (en) * 1975-07-10 1978-03-21 Sener, Tecnica Industrial Y Naval, S.A. Partial secondary barriers for self-supporting, axi-symmetrical tanks on board vessels
US4245748A (en) * 1977-10-20 1981-01-20 Moss Rosenberg Verft A/S Leak protection system on a tank for storing or transporting liquefied gas
WO1992005069A1 (fr) * 1990-09-21 1992-04-02 George Paraskevopoulos Navire-citerne
US6345672B1 (en) * 1994-02-17 2002-02-12 Gary Dietzen Method and apparatus for handling and disposal of oil and gas well drill cuttings
WO1998022335A1 (fr) * 1996-11-22 1998-05-28 Ship Based System As Vaisseau polyvalent
US6745856B2 (en) * 2002-07-17 2004-06-08 M-I, L.L.C. Methods and apparatus for disposing of deleterious materials from a well

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN103693165A (zh) * 2013-12-20 2014-04-02 舟山市蓬莱船舶修造有限公司 船体中化学品独立货舱的制造方法
CN121088323A (zh) * 2025-10-16 2025-12-09 浙江省电力建设有限公司 海水基环保泥浆的智能配比与动态净化循环系统

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