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Publication numberUS2358665 A
Publication typeGrant
Publication dateSep 19, 1944
Filing dateMar 30, 1942
Priority dateMar 30, 1942
Publication numberUS 2358665 A, US 2358665A, US-A-2358665, US2358665 A, US2358665A
InventorsShapiro Abraham
Original AssigneeSocony Vacuum Oil Co Inc
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Method of removing wax deposits from oil-well tubing
US 2358665 A
Abstract  available in
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Claims  available in
Description  (OCR text may contain errors)

,Patented Sept. 19, 1944 METHOD OF REMOVING WAX DEPOSITS FROM OIL-WELL TUBING Abraham Shapiro, Monrovia, Calit, assignor to Socony-V'acuum Oil Company, Incorporated, New York, N. Y., a corporation of-New York No Drawing. Application March 30, 1942, Serial N0. 436,016

4 Claims.

In producing petroleum from some of the deeper wells in California and other localities in which the oil in the formation is at a relatively high temperature, difliculty is often experienced by reason of accumulation of wax deposits in the production tubing. The material of these deposits is-generally similar to the rod wax of the Pennsylvania 011 fields but differs in containing a considerable proportion of bituminous matter and in being of a tougher consistency. Such deposits may occur throughout the entire length of the tubing string but more often are localized and often occur at considerable depth while the tubing above them is substantially clear. Apparently the location of the deposits is governed by temperature changes in the oil column. Wax deposits of this character have caused serious impediment to flow and in some cases complete stoppage, even in wells flowing at high tubing velocity.

These wax-bitumen deposits are substantially completely soluble in certain organic solvents of high specific gravity, such as chloroform, carbon disulfid and carbon tetrachloride, and it has been the practice to keep the tubing clean by periodic injections of one of these solvents, usually carbon tetrachloride. This practice is effective but is unduly expensive by reason of the large quantity of solvent required to remove any deposits distant from the surface. As the tubing is full of petroleum and as the solvent power for the wax-bitumen deposits decreases rather rapidly with progressive dilution, deposits at depth can be removed only by flooding the tubing and thus displacing substantially the entire oil content, an operation consuming a large quantity of costly solvent.

I have discovered that such deposits may be dissolved and removed from the tubing with the consumption of a relatively very small quantity of solvent by the use of an emulsion adapted to break and release the solvent within a definite and rather narrow temperature range and which may therefore be placed at the particular depth at which it is needed. Such emulsions, described below, are immiscible with petroleum and, by reason of their greater specific gravity, sink through the oil column without change until theyreach the temperature level at which they are adapted to break. As the temperature of the 011 column increases progressively from the surface downward and as the temperature gradient of any given well is known or may readily be determined in well known ways, it suflices to adjust the breaking point of the emulsion to the temperature obtaining at the level or levels at which the deposits occur. On reaching this temperature level the emulsion separates, releasing the solvent in undiluted condition and the wax is thereby dissolved and caused to pass out of the tubing.

The emulsions which I have prepared and used for this purpose consist essentially of carbon tetrachloride or an equivalent wax-bitumen solvent (which must be heavierthan and insoluble in water); a petroleum distillate such as the well-known rubber solvent, and a small quantity of water. These liquids are brought into the condition of an emulsion in which the aqueous is the continuous phase by the use of emulsifying agents such as the oil-soluble petroleum sulfonates and agar-agar or a similar gelatinous substance. The control of the breaking temperature, within limits of 25 Fahr. or less, is effected by varying the proportions of sulfonates and gelatinous substance in the composition;

By way of example, a composition resolving spontaneously over the temperature range from 100 to 125 Fahr. may have the following composition, in per cents by weight:

Per cent- Carbon tetrachloride 35.00 Carbon disulfid 40.00

Petroleum distillate 60 A. P. I. gravity..- 14.68

Water 10.00 Oil-soluble sulfonates 0.30 Agar-agar 0.02

This composition is prepared by first dissolving the agar-agar in the water and the sulfonates in the mixture of solvents and then bringing the two phases together with agitation. Preferably the solvent is added very slowly to the aqueous phase with constant stirring over a period of say twenty to thirty minutes. Too rapid an addition of the solvent mixture may cause reversal of the emulsion, which must be of the watera continuous type.

In the same manner an emulsion resolving over the temperature range to 200 Fahr. may be prepared in accordance with the following formula:

Emulsions breaking within temperature ranges intermediate the above may be produced by varying the total dosage of the emulsifying agents. Generally speaking, an increase in the sulfonate dosage of. about 0.25% and of the dose-of agaragar 01' about 0.02% will raise the breaking temperature about 25 Fahr.

Carbon tetrachloride and carbon disuliid are mentioned above as examples oi solvents for a mixture of wax and bitumen. These substances ,may be used singly or in admixture, and may be be completely water-insoluble and must be at least as heavy as water. v

The purpose of the rubber solvent or similar petroleum distillate is to control the specific gravity of the emulsion and cause it to subside through the oil column in the tubing at a desired rate. Resolution due to temperature change is not instantaneous and ii the emulsion subsides too rapidly it might pass in part unbroken through the desired temperature level and thus be wasted. The relation between the solvent and the petroleum distillate is thus variable over a considerable range, remembering that the dilution of the solvent by the distillate somewhat reduces its solvent power for thewax to be removed. The proportion above specifled causes the emulsion to subside through tubingrfllled with oil of 40 A. P. I. gravity at a velocity of about 20 feet per minute.

The oil soluble sulionates referred to herein are the well known "mahogany" sulfonates resulting from the action of strong sulfuric acid on petroleum distillates. Alternatively I may use various oil-soluble sulionated esters or fatty acids, as for example sulfonated' castor oil or sulfonated oleic acid. a In place of agar-agar I may utilize other gelatinous substances such as glue, gelatine, starch, or the water-soluble gums (e. g., gum arabic).

In the use of these emulsions in a flowing well,

the well is shut in and the desired quantity of the emulsion forced into the upper end of the tubing. This quantity should be sumcient to displace the oil from that part of the tubing in which the deposit is known to exist. After this introduction the well is allowed to stand idle for a sufllcient'period to permit the emulsion to reach the predetermined level, to break and to dissolve the wax-bitumen deposit, ordinarily from one to eight hours. .The flow valve is then opened and the solution discharged along with the production normally made by the well.

a,sss,oos

11' the deposits occur along a considerable length of the tubing, or at widely separated intervals. and therefore over a relatively wide temperature range, it may be requisite touse two or more doses of emulsion of diflerent breaking temperatures.

I claim as my ihyention:

1. The method 0% removing wax deposits irom oil-well tubing which comprises: feeding into the upper end or said tubing an emulsion of a solvent for said deposit in a continuous aqueous phase. said solvent being heavier than and insoluble in water and said emulsion being stabilized to break at substantially the temperature at which said wax deposits exist in said tubing by the use in said emulsion of an oil-soluble suli'onated organic body and a water-soluble gelatinous substance.

2. The method of removing wax deposits from oil-well tubing which comprises: feeding into the upper end 01 said tubing an emulsion of a solvent for said deposit in a continuous aqueous phase, saidsolvent being heavier than and insoluble in water and said emulsion being stabilized to break at substantially the temperature at which said wax deposits exist in said tubing by the use in said emulsion of oil-soluble petroleum suli'onates and agar-agar.

3. The method oi removing wax deposits from oil-well tubing which comprises: feeding into the upper end of said tubing an emulsion of a solvent for said deposit in a continuous aqueous phase,

said solvent being heavier than and insoluble inwater and said emulsion being stabilized to break at substantially the temperature'at which said wax deposits exist in said tubing by the use in said emulsion of an. oil-soluble sulionated or ganic body selected from the group consisting of petroleum sulfonates, suli'onated castor oil, and sulfonated, soap-forming fatty acids, and a watersoluble gelatinous substance selected from the group consisting oi agar-agar, starch, glue, gelatine and gum arabic.

4. An agent for removing wax deposits from oil-well tubing comprisingan emulsion of a waterinsoluble, heavier-than-water solvent for said deposits admixed with a minute proportion of an oil-soluble sul'ionated organic body, in a continuous aqueous phase containing a minute proportion of a water-soluble gelatinous substance, said aqueous phase constituting about one-tenth of the volume of said emulsion and being the continuous phase thereof.

ABRAHAM SHAPIRO.

Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US2599729 *Aug 26, 1947Jun 10, 1952Detrex CorpNoncorrosive metal cleaning composition
US2833711 *Oct 4, 1954May 6, 1958Sinclair Oil & Gas CompanyMethod of treating brine disposal wells and composition therefor
US2937112 *Jun 20, 1955May 17, 1960Albert J BoyerMethod for removing paraffin from oil wells, lines, tanks, pumps and the like
US3193499 *Oct 3, 1961Jul 6, 1965Phillips Petroleum CoSolvent and method for removing waxy deposits
US3375192 *Sep 10, 1965Mar 26, 1968Canadian IndMethod for cleaning oil and gas wells employing carbon disulfide-pentane mixtures
US3724552 *Nov 1, 1971Apr 3, 1973Mobil Oil CorpWell treating method to remove paraffin deposition
US3724553 *Nov 18, 1971Apr 3, 1973Mobil Oil CorpParaffin well treatment method
US4148360 *Mar 10, 1978Apr 10, 1979Union Oil Company Of CaliforniaMethod for acidizing high temperature subterranean formations
US4203492 *Feb 22, 1979May 20, 1980Union Oil Company Of CaliforniaMethod for acidizing siliceous materials contained in high temperature formations
US4261421 *Mar 24, 1980Apr 14, 1981Union Oil Company Of CaliforniaMethod for selectively acidizing the less permeable zones of a high temperature subterranean formation
US4267887 *Mar 24, 1980May 19, 1981Union Oil Company Of CaliforniaMethod for acidizing high temperature subterranean formations
US4739833 *Dec 8, 1986Apr 26, 1988Union Oil Company Of CaliforniaMethod of acidizing high-temperature subterranean formations
US5340593 *Mar 15, 1993Aug 23, 1994Union Oil Company Of CaliforniaStabilized solid thiocarbonate
US7497261 *Oct 1, 2007Mar 3, 2009Dyer Richard JMethod for simultaneous removal of asphaltene and/or paraffin and scale from producing oil wells
US9074121 *Feb 24, 2012Jul 7, 2015Richard J. DyerOil well cleaning compositions
US20080047712 *Oct 1, 2007Feb 28, 2008Dyer Richard JMethod for simultaneous removal of asphaltene, and/or paraffin and scale from producing oil wells
US20120234548 *Feb 24, 2012Sep 20, 2012Dyer Richard JOil well cleaning compositions
Classifications
U.S. Classification510/188, 510/461, 510/417, 166/304, 507/211, 507/931, 510/432, 507/212, 507/259
International ClassificationC09K8/524, C10G73/42
Cooperative ClassificationY10S507/931, C09K8/524, C10G73/42
European ClassificationC09K8/524, C10G73/42