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WO2006039362A2 - Procede de chauffage fond de trou - Google Patents

Procede de chauffage fond de trou Download PDF

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Publication number
WO2006039362A2
WO2006039362A2 PCT/US2005/034910 US2005034910W WO2006039362A2 WO 2006039362 A2 WO2006039362 A2 WO 2006039362A2 US 2005034910 W US2005034910 W US 2005034910W WO 2006039362 A2 WO2006039362 A2 WO 2006039362A2
Authority
WO
WIPO (PCT)
Prior art keywords
exothermic
location
chemical
group
hydration
Prior art date
Legal status (The legal status 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 status listed.)
Ceased
Application number
PCT/US2005/034910
Other languages
English (en)
Other versions
WO2006039362A3 (fr
Inventor
Ronald G. Bland
David B. Young
Marvin L. Pless
John B. Trenery
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Baker Hughes Holdings LLC
Original Assignee
Baker Hughes 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 Baker Hughes Inc filed Critical Baker Hughes Inc
Publication of WO2006039362A2 publication Critical patent/WO2006039362A2/fr
Publication of WO2006039362A3 publication Critical patent/WO2006039362A3/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

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
    • E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • E21B36/008—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using chemical heat generating means
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection

Definitions

  • the present invention relates to methods and compositions for providing controlled downhole heating, such as in a subterranean reservoir during a hydrocarbon recovery operation.
  • Drilling fluids used in the drilling of subterranean oil and gas wells along with other drilling fluid applications and drilling procedures are known.
  • drilling fluids also known as drilling muds, or simply "muds".
  • the drilling fluid is expected to carry cuttings up from beneath the bit, transport them up the annulus, and allow their separation at the surface while at the same time the rotary bit is cooled and cleaned.
  • a drilling mud is also intended to reduce friction between the drill string and the sides of the hole while maintaining the stability of uncased sections of the borehole.
  • the drilling fluid is formulated to prevent unwanted influxes of formation fluids from permeable rocks penetrated and also often to form a thin, low permeability filter cake which temporarily seals pores, other openings and formations penetrated by the bit.
  • the drilling fluid may also be used to collect and interpret information available from drill cuttings, cores and electrical logs.
  • the term "drilling fluid” also encompasses "drill-in fluids" and "completion fluids”. Drilling fluids are typically classified according to their base fluid. In water-based muds, solid particles are suspended in water or brine. Oil can be emulsified in the water. Nonetheless, the water is the continuous phase.
  • Oil- based muds are the opposite or inverse. Solid particles are suspended in oil, and water or brine is emulsified in the oil and therefore the oil is the continuous phase. Oil-based muds that are water-in-oil emulsions are also called invert emulsions. Brine-based drilling fluids, of course are a water- based mud in which the aqueous component is brine. It is apparent to those selecting or using a drilling fluid for oil and/or gas exploration that an essential component of a selected fluid is that it be properly balanced to achieve the necessary characteristics for the specific end application. Because drilling fluids are called upon to perform a number of tasks simultaneously, this desirable balance is not always easy to achieve.
  • bitumen or "tar” beds are encountered. These beds are commonly found during sub-salt drilling in the Gulf of Mexico, but also at other locations. Indeed, the bitumen occurs so frequently in the Gulf of Mexico formations that it has been likened to a "river” of tar. Drilling through thin bitumen beds is generally no more than a minor nuisance, but thick beds can result in stuck pipe, stuck casing, side ⁇ tracks, loss of hole and other problems that can cost the well operators millions of dollars.
  • One of the most precarious operations is running casing after drilling through a bitumen bed due to the movement or "flow" of the bitumen into the borehole before casing can be picked up and run to bottom.
  • Oil sands are a mixture of grit and bitumen.
  • the deposits are generally either minded in massive open pits, or if too deep for surface mining, are injected with steam to coax the viscous bitumen to flow into wells.
  • Gas hydrates are solid inclusion compounds resembling ice. Gas hydrates occur when water molecules form a cage-like structure around smaller "guest molecules". The most common guest molecules are methane, ethane, propane, isobutene, n-butane, nitrogen, carbon dioxide and hydrogen sulfide, of which methane occurs most abundantly in naturally-occurring hydrates. In nature, one cubic meter of hydrate may contain up to about 164 m 3 of methane. Gas hydrates occur wherever the conditions within the sediments are in a methane-hydrate stability region and where methane and water are available.
  • gas hydrates are stable at low temperatures and/or high pressure. Because of the requirements of pressure and temperature, and because of the requirement of relatively large amounts of organic matter of bacterial methanogenesis, gas hydrates are primarily restricted to two regions: high latitudes and along the continental margins in oceans. In polar regions, the gas hydrates are commonly linked to permafrost occurrence onshore and on the continental shelves. In the oceans, gas hydrates are found in outer continental margins, where the supply of organic material is high enough to generate enough methane, and with water temperatures close to freezing.
  • the oceanic gas hydrate reservoir has been estimated to be about 10,000 to 11 ,000 GtC (Gigatons carbon; 1.0 x 10 7 to 1.1 x 10 7 teragrams).
  • the permafrost reservoir has been estimated at about 400 GtC (4.0 x 10 5 teragrams), but no estimates have been made of possible Antarctic reservoirs. Given the amount of hydrocarbons bound in gas hydrates, many are exploring the possibility of recovering hydrocarbons from this source.
  • compositions and methods could be devised to provide localized heating to soften the bitumen to help facilitate movement of the casing or liner through the bitumen to the bottom. It would also be desirable if compositions and methods could be devised to provide controlled localized heating to melt in-situ gas hydrates in order to produce the large quantities of natural gas they contain. Further, it would be helpful to facilitate controlled localized heating of oil sands to improve recovery of hydrocarbons from that source.
  • a method for providing localized heating in a subterranean formation that involves placing at a location in the subterranean formation in any order: an exothermic hydration chemical and an amount of water in contact with the exothermic hydration chemical effective to cause an exothermic reaction thereby heating the location and a suitable medium for transporting the heat source to the desired location.
  • a method for providing localized heating in a subterranean formation involves placing at a location in the subterranean formation where bitumen is present in any order: an exothermic hydration chemical and an effective amount of water in contact with the exothermic hydration chemical to cause an exothermic reaction without generating an appreciable amount of gas; and heating the location sufficiently to at least soften the bitumen.
  • a method for providing localized heating in a subterranean formation involves placing at a location in the subterranean formation containing gas hydrates an exothermic hydration chemical, and reacting at least a portion of the water in the gas hydrates with the exothermic hydration chemical to cause an exothermic reaction to release at least a portion of hydrocarbons bound in the hydrates.
  • an appreciable amount of gas may or may not be released and water may or may not be added to the formation.
  • a method has been discovered to generate localized heat remotely downhole using heat of hydration as a heat source. It has been estimated in one non-limiting embodiment, if the bitumen in the "river of tar" beneath the Gulf of Mexico is heated to about 220 to about 230 0 F (about 104 to about 110 0 C), the material would be 10 times less viscous. Most exothermic oxidation/combustion reactions require temperatures that would compromise mud/spot stability, if not tubular integrity, would tend to be difficult to initiate and would be problematic to formulate as a liquid or mud for downhole use. Initiating the reaction at the surface would tend to expend and dissipate most of the heat before placement in the target or the mud for downhole use.
  • Hydration of acidic electrolytes such as aluminum chloride, AICI 3
  • acids would be expected to be corrosive and at high temperatures could compromise the integrity of the tubular goods, tools and other equipment in many circumstances.
  • hydration of aluminum chloride would produce a product environment of about pH 0.8, as contrasted with using NaOH, which would generally yield a product environment of about pH 14.
  • Oil field chemistries are generally and preferably alkaline at least in part to avoid or minimize corrosion concerns.
  • the process in one non-limiting embodiment uses a binary design where in one non-limiting embodiment the "fuel” is placed first as a slurry or suspension or fluid combined with an "initiator", e.g. water that produces heat precisely at the point or location of interest.
  • an initiator e.g. water that produces heat precisely at the point or location of interest.
  • the binary components may be placed at the location in any order, in most embodiments it is expected that the "initiator” (e.g. water) would be placed last in sequence
  • Heat of hydration is defined as the heat evolved (or absorbed) when a hydrate of a compound is formed.
  • the exothermic hydration chemical has a heat of hydration of at least 40 kJ/mol, and alternatively has a heat of hydration of at least 80 kJ/mol.
  • the exothermic hydration chemical should be a material that when combined with the initiator generates sufficient heat to soften, melt or flow the bitumen, but without generating an appreciable amount of gas.
  • Many exothermic reactions give large amounts of heat, but produce relatively large amounts of gas - a thermite reaction, for example. However, such an exothermic reaction downhole could cause a blowout of the well and is extremely undesirable.
  • an appreciable amount of gas is defined as an amount that would interfere with normal hydrocarbon recovery operations and does not include incidental or non-problematic amounts. It should be understood that avoiding the generation of an appreciable amount of gas does not mean that water vapor may not be evolved. It is acceptable in all embodiments herein for water vapor to be evolved or generated in the process of remote heating a location or formation.
  • tar or bitumen such as oil sands or subterranean bitumen layers
  • these environments are generally non-aqueous, that is, they do not contain appreciable amounts of water.
  • the water is delivered as part of the method to be a co-reactant with the exothermic hydration chemical.
  • the exothermic hydration chemical is used to generate heat in a subterranean gas hydrate formation (e.g. in a permafrost region on land or sub-ocean)
  • the generation of appreciable amounts of gas is acceptable - and in fact is desirable since it is expected to be the primary way in which hydrocarbons (e.g. methane) is released.
  • this embodiment uses a unitary design; it is contemplated that in most cases only the exothermic hydration chemical would be delivered or pumped to the gas hydrate formation or region since the hydrates themselves would provide the source of most of the water. Alternatively, additional water may be added as necessary or desired.
  • a goal of recovering hydrocarbons from gas hydrates is to either deliver heat (increase temperature) or reduce pressure, or both.
  • the temperature of the gas hydrates need only be raised 2 or 3 0 C for the gas hydrate to decompose and the guest molecules released.
  • reactants either the "fuel” or “initiator” that would be too exotic or expensive to use in the quantities necessary for heating a location in a subterranean reservoir.
  • water Since water is a highly accessible and cheap material, it is one non-limiting choice for initiator that may be used. Additionally, water has a very high specific heat and thus will retain the heat well for a period of time for the purpose of softening and/or melting the bitumen or heating in situ gas hydrate formations.
  • Factors to be considered in selecting the binary reactants include, but are not necessarily limited to the expected amount of heat output (for instance measured in kJ/mol), the cost, the acidity of the resulting products, the solubility of the "fuel” or exothermic hydration chemical, HS&E profile
  • a suitable "fuel" or exothermic hydration chemical to react with water in a hydration reaction includes, but is not necessarily limited to, a relatively neutral electrolyte, a metal oxide, a metal hydroxide, and an organic compound.
  • relatively neutral electrolytes include, but are not necessarily limited to, halogen salts such as calcium chloride, magnesium chloride, lithium chloride, and lithium bromide and mixtures thereof and the like.
  • relatively neutral electrolytes include sulfate salts such as magnesium sulfate, calcium sulfate, and the like.
  • Relatively neutral refers to an electrolyte that is not strictly neutral, but which is sufficiently neutral for the purposes of the process described herein.
  • An example of a non-neutral electrolyte that could be considered is aluminum chloride, which could be useful under certain specialized situations.
  • metal oxides include, but are not necessarily limited to, calcium oxide, strontium oxide, barium oxide, and mixtures thereof and the like.
  • metal hydroxides include, but are not necessarily limited to, sodium hydroxide (NaOH), potassium hydroxide (KOH), lithium hydroxide (LiOH), cesium hydroxide (CsOH) and mixtures thereof and the like.
  • suitable organic compounds include, but are not necessarily limited to, peroxides, epoxides and monomers whose polymerization would generate heat such as acrylates, methacrylates and mixtures thereof and the like.
  • Other reactants that can be used to generate localized heating but might be limited in their uses due to appreciable amounts of gas produced are acid compounds such as hydrogen bromide, hydrogen chloride, hydrogen iodide, and percholoric acid. Reactions other than exothermic hydration reactions could be used to provide localized heating in certain situations. These reactions are typically not desirable for the bitumen-heating embodiment of the invention due to the by-products produced.
  • Slurry placement of the "fuel” or exothermic hydration chemical is anticipated where the "fuel” would settle out in the zone of interest to concentrate the fuel as much as possible in the desired location.
  • a stable slurry may be desirable or preferred in a method of delivery and/or placement at the desired location.
  • stable is meant that the slurry does not separate or settle upon standing for periods of time. In the case of the stable slurry, it would be pumped downhole to a location or against a structure and pack off like a packed bed. The more densely packed the bed, the more heat generated, and the more effective the process.
  • the slurry must consist of an organic base fluid and preferably one that has a low specific heat.
  • the fluid should also a high thermal conductivity in order to transfer the generated heat effectively.
  • fluid mediums include, but are not necessarily limited to, alcohols, glycols, alcohol/glycol blends, specifically designed heat transfer fluids, such as Dowtherm ® fluids (available from Dow Chemical Company) and Therminol ® fluids (available from Solutia Inc.), esters either natural such as vegetable oils and/or animal oils or synthetic esters such as 2-ethylhexyl esters of fatty acids and hydrocarbon oils either distillates or synthetic.
  • placement could involve encapsulating the fuel or exothermic hydration chemical, such as with a wax; a polymer wax or other polymer or material that melts or disintegrates or dissociates at the location.
  • suitable polymeric materials include, but are not necessarily limited to, hydrocarbon waxes such as paraffin waxes and microcrystalline waxes, vegetable or animal waxes, solid relatively weak acids such as tallow or hydrogenated tallow fatty acid, polybutylene, polymethacrylates, polyethylene glycol (PEG), methoxylated PEG, polyethylene oxide (PEO), polyethylene waxes, polypropylene glycol (PPG), and the like.
  • suitable encapsulating material includes ionomeric waxes, including, but not necessarily limited to, PEG (e.g.
  • alkoxy terminated PEG e.g. methoxylated PEG or mPEG
  • PEO polypropylene oxide
  • PPO polypropylene oxide
  • the encapsulation may be extended to PEG/PPG, PEG/PEO, and mPEG/PEG blends of different molecular weights. Polymerization of these polymer shells is well known in the art. Other extended release forms include, but are not necessarily limited to, peptization with binder compounds, absorbed or some other method of layering on a small particle or porous substrate, and/or a combination thereof. Specifically, the fuel or exothermic hydration chemical may be encapsulated to permit slow or timed release thereof.
  • the coating material may slowly dissolve or be removed by any conventional mechanism, or the coating could have very small holes or perforations therein for the exothermic hydration chemicals within to diffuse through slowly.
  • polymer encapsulation coatings such as used in fertilizer technology available from Scotts Company, specifically POLY-S ® product coating technology, or polymer encapsulation coating technology from Fritz Industries could possibly be adapted to the methods herein.
  • the sources could also be absorbed onto zeolites, such as Zeolite A, Zeolite 13X, Zeolite DB-2 (available from PQ Corporation, Valley Forge, Pennsylvania) or Zeolites Na-SKS5, Na-SKS6, Na-SKS7, Na-SKS9, Na-SKSI O, and Na-SKSI 3, (available from Hoechst Aktiengesellschaft, now an affiliate of Aventis S. A.), and other porous solid substrates such as MICROSPONGETM (available from Advanced Polymer Systems, Redwood, California) and cationic exchange materials such as bentonite clay or microscopic particles such as carbon nanotubes or buckminster fullerenes.
  • zeolites such as Zeolite A, Zeolite 13X, Zeolite DB-2 (available from PQ Corporation, Valley Forge, Pennsylvania) or Zeolites Na-SKS5, Na-SKS6, Na-SKS7, Na-SKS9, Na-SKSI O, and Na-SKSI 3, (available from Hoech
  • the component sources may be both absorbed into and onto porous substrates and then encapsulated or coated, as described above. Melting would occur at the location temperature, and disintegration or dissociation may occur due to a change in temperature, pressure, chemical environment, a combination of these or other forces.
  • An encapsulated exothermic hydration chemical could be suspended in an aqueous carrier at the surface and pumped downhole for placement, such as in the previously mentioned slurries.
  • the wax or other coating would be chosen to melt at the temperature of the target zone or just before exposing the fuel and/or chemical to the water in the carrier at that time.
  • encapsulation includes, but is not necessarily limited to, microencapsulation.
  • one non-limiting example of the invention would be drilling out the bitumen inside of a stuck liner, spotting a caustic soda/"oil" or hydrocarbon slurry inside the liner opposite or adjacent to the bitumen zone, allowing the caustic soda beads/powder to settle, and slowly pumping an aqueous fluid to hydrate the caustic soda to generate localized heating.
  • the invention will be further illustrated with respect to the following
  • Example 1 Use of 40 wt% NaOH in oil does not generate heat, but when contacted with a water-based mud would give 186,000 Btu/bbl (1.2 MJ/litre).
  • Example 2 Use of 40 wt% NaOH in oil does not generate heat, but when contacted with a water-based mud would give 186,000 Btu/bbl (1.2 MJ/litre).
  • compositions and methods described herein may be used to help recover hydrocarbons from oil sands.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Working-Up Tar And Pitch (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

La présente invention concerne un procédé dans lequel des électrolytes neutres, des électrolytes relativement neutres, des oxydes métalliques, des hydroxydes métalliques et/ou des substances chimiques d'hydratation exothermiques organiques peuvent être hydratés avec de l'eau à un emplacement précis d'une formation souterraine pour produire suffisamment de chaleur exothermique pour au moins amollir et si possible faire fondre et s'écouler du bitume à un emplacement ou à proximité d'un emplacement. Ce procédé de chauffage contrôlé et localisé peut être utilisé dans des applications de forage à travers des couches épaisses de bitume ou de goudron. Dans un mode de réalisation non limitatif, la réaction d'hydratation exothermique ne produit pas de quantités importantes de gaz. La réaction exothermique peut également être utilisée pour libérer des hydrocarbures d'hydrates de gaz dans un mode de réalisation dans lequel l'évolution de gaz est acceptable.
PCT/US2005/034910 2004-09-29 2005-09-29 Procede de chauffage fond de trou Ceased WO2006039362A2 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US61412904P 2004-09-29 2004-09-29
US60/614,129 2004-09-29
US11/237,074 2005-09-28
US11/237,074 US20060081374A1 (en) 2004-09-29 2005-09-28 Process for downhole heating

Publications (2)

Publication Number Publication Date
WO2006039362A2 true WO2006039362A2 (fr) 2006-04-13
WO2006039362A3 WO2006039362A3 (fr) 2006-07-20

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WO2008107798A3 (fr) * 2007-03-05 2010-05-20 Louis Wardlaw Dispositif chauffant pour passage formé dans une formation souterraine contenant de l'asphalte et procédé d'utilisation
CN101952356B (zh) * 2008-02-01 2012-12-05 万喜路桥公司 放热混合物用于制造沥青混凝土的用途

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