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Publication numberWO1996037683 A1
Publication typeApplication
Application numberPCT/GB1996/001238
Publication date28 Nov 1996
Filing date23 May 1996
Priority date24 May 1995
Publication numberPCT/1996/1238, PCT/GB/1996/001238, PCT/GB/1996/01238, PCT/GB/96/001238, PCT/GB/96/01238, PCT/GB1996/001238, PCT/GB1996/01238, PCT/GB1996001238, PCT/GB199601238, PCT/GB96/001238, PCT/GB96/01238, PCT/GB96001238, PCT/GB9601238, WO 1996/037683 A1, WO 1996037683 A1, WO 1996037683A1, WO 9637683 A1, WO 9637683A1, WO-A1-1996037683, WO-A1-9637683, WO1996/037683A1, WO1996037683 A1, WO1996037683A1, WO9637683 A1, WO9637683A1
InventorsHugh Malcolm Bourne, Thomas Anthony Lawless, Roger Neal Smith
ApplicantAea Technology Plc
Export CitationBiBTeX, EndNote, RefMan
External Links: Patentscope, Espacenet
Well inhibition
WO 1996037683 A1
Abstract
Deleterious processes such as scale deposition in an oil well extending through a formation are inhibited by injecting an emulsion into the formation. The emulsion contains an aqueous solution of an inhibitor as a dispersed phase in an oil phase such as kerosene. The emulsion is arranged to break down when injected into the formation, for example by an appropriate choice of surfactant, so the inhibitor is adsorbed or precipitated in the formation. The use of the emulsion can be advantageous in wells with poor pressure support, and in formations susceptible to deconsolidation by acids.
Claims  (OCR text may contain errors)
Claims
1. A method of inhibiting deleterious processes in a well extending through a formation, the method comprising injecting into the formation an emulsion containing an aqueous solution of an inhibitor or an inhibitor component as a dispersed phase in an oil phase, the emulsion being such that the phases separate after injection into the formation, due to inherent properties of the emulsion and the temperature and/or time and/or mechanical stress to which it is subjected.
2. A method as claimed in Claim 1 wherein the phases of the emulsion separate as a result of a change of temperature.
3. A method as claimed in Claim 1 or Claim 2 wherein the oil phase is a dispersed phase within a continuous external aqueous phase.
4. An emulsion suitable for use in a method as claimed in any one of the preceding Claims.
Description  (OCR text may contain errors)

Well Inhibition

This invention relates to a method of inhibiting deleterious processes in a well such as an oil well, particularly but not exclusively for inhibiting scale deposition.

It is known to supply inhibiting chemicals to oil wells (and gas wells) to suppress processes such as corrosion, scale deposition, or emulsification which might otherwise occur. Such inhibitors may be supplied in the form of solutions in either water or in an oil like liquid such as kerosene. A wide variety of scale inhibitors are known; and scale inhibitors may be injected or squeezed into the rock formation surrounding a well, so that the inhibitor chemicals are gradually released into the produced fluids over a period, possibly of several months. The inhibitor in some cases is adsorbed by the formation, while with other formulations it is precipitated. For example US 4 947 934 (Hen; Mobil Oil) describes a method of scale inhibition in which an acidic aqueous solution containing polyacrylate inhibitor and a polyvalent cation are injected into the formation. EP 0 371 667 A (Conoco) describes the injection of an aqueous solution of a phosphonate inhibitor and a metal chelate, the cheϊate having a lower stability constant than the inhibitor, so precipitation of the metal phosphate occurs in the formation. GB 2 250 738A (Marathon Oil) describes the use, in a squeeze treatment to inhibit scale, of an aqueous solution of a polyvinyl sulphonate of molecular weight above 9000. EP 0 030 425 A (Cyanamid) describes the use, in a squeeze treatment, of an emulsion comprising a water-soluble polymeric antiprecipitant dispersed in an oil phase, with at least two surfactants which ensure that the emulsion inverts or breaks on contact with water, to release the antiprecipitants.

According to the present invention there is provided a method of inhibiting deleterious processes in a well extending through a formation, the method comprising injecting into the formation an emulsion containing an aqueous solution of an inhibitor or an inhibitor component as a dispersed phase in an oil phase, the emulsion being such that the phases separate after injection into the formation, due to inherent properties of the emulsion and the temperature and/or time and/or mechanical stresses to which it is subjected.

The breakdown of the emulsion and consequent separation of the phases may occur as a result of a change of temperature, or simply as a result of the time which has elapsed whilst resident in the formation. The breakdown thus does not depend upon the nature of the other fluids encountered by the emulsion within the formation. As the emulsion breaks down the inhibitor is adsorbed or precipitated onto the formation.

It will be appreciated that the aqueous solution may include liquids other than water, for example alcohols, as long as they are not soluble in the oil phase; and that additional materials other than the inhibitor may be dissolved in it. The term "oil phase" means a relatively non-polar substance which. is not soluble in the aqueous solution, and which is miscible with any crude oil produced from the formation. A suitable oil phase is kerosene.

In general a separate surfactant or emulsifying agent will also be required to form the emulsion, which is preferably a non-ionic emulsifier as such e ulsifiers tend to tolerate changes in salinity while being sensitive to temperature. The emulsifier must have a hydrophilic/lipophilic balance (HLB) suited to the other liquids present in the emulsion, and an HLB value less than 8 is generally desirable for forming such a water- in-oil ('invert') emulsion. Examples of emulsifiers which may be suitable are alkoxylated amines, glycols or substituted phenols, ethoxylates, or sulphonates. Indeed the emulsion may contain more than one emulsifier.

The invention provides particular benefit when used in a low flow oil well, where the pressure causing oil to flow into the well may be insufficient to displace water from the formation if the well is subjected to a conventional squeeze with an aqueous inhibitor solution. It also is beneficial in wells where the formation is calcite-cemented sandstone, as many conventional aqueous inhibitors are acidic and so cause extensive deconsolidation of the formation.

In a modification, the oil phase is itself a dispersed phase within a continuous external aqueous phase: thus the emulsion is a water-in-oil-in-water emulsion. In this case the two aqueous phases (the dispersed aqueous phase and the continuous aqueous phase) may contain different inhibitor components which react when the emulsion breaks down. For example the dispersed aqueous phase may contain a phosphonate, or a polycarboxylic acid or a polyacrylic acid (e.g. phosphinopolycarboxylic acid, or diethylenetriaminepenta- (methylenephosphonic acid) , as described in US 5 090 479 (Read/Statoil) ) , and the continuous aqueous phase contain a dissolved calcium salt such as CaCl2. The use of such a three-phase emulsion provides the same benefit mentioned above in formations susceptible to deconsolidation by acids.

Thus the concept of the invention is to inject into the formation an invert emulsion with an inhibitor such as a scale inhibitor in the dispersed, aqueous phase. At a defined temperature/time (appropriate to field conditions) the emulsion resolves to release the aqueous inhibitor into contact with surfaces of pores in the formation, so the inhibitor is retained on those surfaces, whilst the oleic phase remains in continuity with oil in adjacent pores so that subsequent flow of oil through the formation is not suppressed.

The invention will now be further and more particularly described, by way of example only. One example is in providing scale inhibitor into an oil well which has poor pressure support, and so low oil flow, so that it is preferable to maintain oil phase continuity through the pores of the formation. The scale inhibitor in this particular example is sodium polyacrylate containing a phosphorus label (Bevaloid IP-12B; trade mark) as a 2% aqueous solution; this is mixed with an oil phase such as kerosene and a suitable surfactant, and blended at high speed (for example with a Silverson blender; trade mark) so as to form an invert emulsion. The invert emulsion is then injected into the formation, where it breaks down to allow the inhibitor to be retained. The oil well can then come back on stream again rapidly, as an oil phase is still present in the pores of the formation.

It will be appreciated that the physical parameters such as temperatures in the region of the formation into which injection is to be performed will be different for different wells, and so the invert emulsion has to be suited to that well. For example in one well it may be desirable for the emulsion to break down at 115C, while in another well the break-down temperature (i.e. the temperature in the formation where break down is to occur) might be 130C or 75C. It may also be necessary for the emulsion to remain in the formation (and so at elevated temperature) for a prolonged time such as 1 hour or 6 hours, before it breaks down. Furthermore the emulsion should be stable in contact with oil field liquids such as oil or brine; it should have a viscosity similar to or greater than that of the oil in the well, and it is preferably not affected by any shear effects experienced during injection. It is thus clear that the emulsion, and in particular the surfactant, must be selected and formulated to suit a particular well.

Surfactants can readily be selected for this use, as they should generally have an HLB value less than 8 in order to stabilise an invert emulsion, more preferably between 3 and 6. It will be appreciated that a mixture of different surfactants, differing in their HLB values, may be used. Another criterion which can sometimes provide guidance is the cloud point of the surfactant, that is the temperature at which an aqueous solution of the surfactant becomes cloudy as the surfactant comes out of solution; the cloud point temperature provides an indication of the temperature at which the emulsion can be expected to break.

For example a suitable emulsion might use as the continuous (oil) phase kerosene, or a mixture of kerosene with oil, or a long chain alcohol (e.g. C10) , or esters, which are compatible with the oil from the well. As discussed earlier the aqueous phase contains the scale inhibitor; it might be seawater or demineralised water, and should be of suitable pH to maximise inhibitor retention in the formation. The surfactant might for example be a mixture of 2 parts sorbitan trioleate (with HLB = 1.8) to 15 parts sorbitan mono-oleate (with HLB = 4.3), so the resultant HLB is about 4.0. These surfactants are available for example from Croda Chemicals, Goole, England and are widely used as industrial water-in-oil emulsifiers. Other surfactants which might be used are glycerol mono-oleate (HLB = 3.4), glycerol monostearate (HLB = 3.8), or glycerol monolaurate (HLB = 5.2) . Alternatively the surfactant might be a non-ionic block copolymer, such as a copolymer of polyhydroxy fatty acid and polyalkyleneglycol; such a copolymer is Hypermer B246 or Hypermer B239 (trade marks), and has an HLB value of about 6.0. Such surfactants tend to be substantially insoluble in water, so the emulsion is made by dissolving the surfactant in the selected oil phase, before mixing vigorously with the aqueous phase.

The quantity of surfactant is preferably between about 1% and 5% by weight, for example between 2% and 3%. This can be expected to provide some excess surfactant, in the event that there is some adsorption of surfactant by rock surfaces. The quantity of the aqueous phase is preferably in the range 20% to 50% by weight, the remainder being the oil phase, so that the volume of the aqueous phase is less than that of the oil phase. The resulting emulsion desirably has a viscosity higher than that of the oil in the formation, though preferably not more than two hundred times, more preferably between 1.5 and 20 times the viscosity of the formation oil, for example about 2 or 10 times.

It will be appreciated that the selection of the components and their proportions must be chosen to suit a particular well, taking into account the temperature in the formation, and the properties of the oil in that formation. It will be also appreciated that other types of surfactant may be used in place of or mixed with those discussed above, for example a high molecular-weight fatty amine blend (cationic, with HLB of about 4.5) or calcium stearoxyl-2-lactylate (anionic, with HLB of 5.1). Water-in-oil emulsions made with ionic surfactants such as these will tend to invert when the temperature is raised, although the emulsion can also be affected by the salt concentration. In any event as an emulsion is left in contact with rock surfaces there may be adsorption of surfactant onto those surfaces, and possibly also hydrolysis of surfactant, so that the critical monomer concentration in the oil phase is no longer exceeded (as is required for stability) , so the emulsion breaks down.

Patent Citations
Cited PatentFiling datePublication dateApplicantTitle
EP0030425A1 *21 Nov 198017 Jun 1981Cyanamid Of Great Britain, LimitedMethod of inhibiting precipitation of salts from water dispersed in oil and compositions containing polymeric antiprecipitants
EP0447120A1 *7 Mar 199118 Sep 1991Mobil Oil CorporationA liquid membrane catalytic scale dissolution method
GB2244073A * Title not available
US3185217 *20 May 196325 May 1965Exxon Production Research CoWell treatment to remove permeability block
US3799265 *15 Jan 197326 Mar 1974Marathon Oil CoUse of micellar solution as an emulsion breaker
Referenced by
Citing PatentFiling datePublication dateApplicantTitle
WO2001059255A1 *7 Feb 200116 Aug 2001Statoil AsaMethod of treating reservoir zone of hydrocarbon producing well to inhibit water production problems
WO2005066299A1 *28 Dec 200421 Jul 2005Schlumberger Canada LimitedA method of gravel packing with oil-based carrier fluid
US715617723 Jul 20012 Jan 2007Schlumberger Technology CorporationScale dissolver fluid
US73439789 Nov 200618 Mar 2008Schlumberger Technology CorporationScale dissolver fluid
US741900430 Dec 20032 Sep 2008Schlumberger Technology CorporationMethod of gravel packing with oil-based carrier fluid
US767099511 Jul 20012 Mar 2010Schlumberger Technology CorporationViscoelastic wellbore treatment fluid
US785856314 Jan 201028 Dec 2010Schlumberger Technology CorporationWellbore treatment with hydrocarbon-responsive fluid containing oligomeric viscoelastic surfactant
Classifications
International ClassificationC09K8/528
Cooperative ClassificationC09K2208/14, C09K8/528
European ClassificationC09K8/528
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