US3043072A

US3043072A - Method and means for treatment of oil well production

Info

Publication number: US3043072A
Application number: US806000A
Authority: US
Inventors: Jay P Walker; Clarence O Glasgow
Original assignee: National Tank Co
Current assignee: Cameron Solutions Inc
Priority date: 1959-04-13
Filing date: 1959-04-13
Publication date: 1962-07-10
Anticipated expiration: 1979-07-10

Description

July 10, 1962 J. P. WALKER ETAL METHOD AND MEANS FOR TREATMENT OIL WELL PRODUCTION 4 Sheets-Sheet 1 Filed April 13, 1959 30 GAS OUTLET T RW T E O m n mg M T u M u 0 MA d e 0 VW. L M m o 6 a M m. a 0

WELL amt-AM I INLET WATER our/.57

DRAIN A 1' TODNEY July 10, 1962 J. P. WALKER ETAL 3,043,072

METHOD AND MEANS FOR TREATMENT OF OIL WELL PRODUCTION Filed April 15, 1959 4 Sheets-Sheet 2 GAS OUTLET WELL STREAM INLET INVENTORIS JA R WALK2 CLAQENCE 0. eusaow ATTORNEY July 10, 1962 J. P. WALKER ETAL METHOD AND MEANS FOR TREATMENT OF OIL WELL PRODUCTION 4 Sheets-Sheet 3 Filed April 13, 1959 GAS OUTLET no 011. OUTLET J/84- WELL .S'TPEAM INLET WATER 0U TL E T- v INlfENTORIS' JAY WALKER CLARENCE 0. ezjow ATTORNEY 4 Sheets-Sheet 4 \iailvlil: 2,

W T M T m M H N 0K1. N F- TLG L NA. R T M T E 0 w w w w m Y 5 L U T m A E A JI- o w w c 5 L 2 2 Y 6 a I .H I A B m T I= w Li H Mir.

Jul 10, 1962 J. P. WALKER ETAL METHOD AND MEANS FOR TREATMENT OF OIL WELL PRODUCTION Filed April 13, 1959 iifididlz Patented July 30, lQ fiZ a Ti 3,043,072 METHQD AND lvdlANd FUR TREATMENT QB {3E WELL PRGDUCTEGN Jay P. Walker and Clarence 0. Glasgow, Tulsa, Gltla,

assignors to National Tani; Company, Tulsa, Okla, a

corporation of Nevada Filed Apr. 13, 1959, Ser. No. 896,000 7 Claims. (Cl. 5545) This invention relates to new and useful improvements in method and means for treating oil well emulsion streams.

The invention is directed primarily to the heater type of emulsion treater and is particularly concerned with the efiicient and effective condensation of valuable light hydrocarbons from the gas evolved during the heating of the well stream of emulsion. Application of heat breaks the well stream, or emulsion, into its components. Chemical mixed with the well stream, or emulsion, furthers this process. However, some hydrocarbons are driven from a liquid state into a vapor state by this heat. The lighter of these hydrocarbons, such as methane, ethane and propane cannot be held in a liquid state at ambient temperature and pressure. However, heavier hydrocarbons, driven from their liquid state by the evolvement of these lighter hydrocarbons into gas, are also in danger of being lost from the treating process as vapor. Therefore, recovery of these hydrocarbons which are liqueiiable at ambient conditions is desirable to increase both the volume and gravity of the clean oil produced.

The pressures at which well streams are produced vary widely. -i the reduction of production pressure to treating pressure is made in one step, many liquefiable hydrocarbons may be carried away as gas and lost to the recovered liquids. Therefore, any multiplicity of pressure reduction steps helps separate the lighter hydrocarbons more slowly so fewer of the heavier hydrocarbons will be driven into the gaseous state. An intermediate result of using multiple stage separation is to provide additional liquid hydrocarbons for the heating and stabilizitaon portions of a treating process. The ultimate result is to increase the quantity and gravity of liquefied hydrocarbons recovered at ambient conditions.

in addition to the problem of conserving both the quantity and gravity of the clean oil produced by heat treating, there is another problem in conserving the heat required for the process. Of course, it is economically desirable to consume and waste as little heat as possible in the water of the well stream. Structure, and arrangement of structure, which will enable the heat of the source to be placed directly into the portion of the well stream requiring the heat for treating, and which will keep the transfer rate near its maximum, will enable the heat source to be fired at the lowest, more efficient, rate.

A principal object of the present invention is to condense fractions from all gaseous hydrocarbons evolved from heat-treating oil well emulsions and return the hydrocarbon condensate to the heat-treating process for further stabilization.

Another object is to prepare oil well emulsions for heat-treating by reducing the pressure on the emulsion so as to provide a max mum of hydrocarbon liquid for heat-treating. The ultimate condensation of all gaseous hydrocarbons evolved from the'heat-treatment will return additional quantities of liquid hydrocarbons to the heat-treating process for further stabilization and removal of water from the process.

Another object is to condense water vapor from all the mixture of hydrocarbon and water vapor evolved from heat-treating oil well emulsion and maintain the condensed water isolated from the clean oil produced by the process while disposing of the water.

Another object is to utilize the cooling capacity of oil well production in condensing fractions from all gaseous hydrocarbons evolved from heat-treating the production and maintain the condensed fractions isolated from the clean oil produced while returning the condensed fractions to the production, before the production is heat treated, for further stabilization.

Another object is to utilize the cooling capacity of the oil well production stream to condense fractions from all gaseous hydrocarbons evolved from the heat-treating of the production and to use the oil well production stream to cool the clean oil produced by the treatment and to combine condensed hydrocarbons with the production, as the production is passed to the heat-treatment, for further stabilization of the condensed hydrocarbons.

Another object is to provide isolation for oil and emulsion in an area large enough for efficient Stratification of the liquid components of a well stream in a heat treating process and heat transfer from a heatsource into the emulsion, or oil, strata to thoroughly mix the emulsion with any added chemical and degas the emulsions.

Another object is to provide for selective heating of the emulsion and oil components of a well stream while the gaseous component developed is removed, in isolation, to a condensing location. Emulsion and oil, which has been heated, is continually removed from the upper portion of the strata of the emulsion and oil and coalesced into clean oil and water.

The present invention contemplates applying heat to an oil well emulsion to resolve it into its components. All the gaseous component is indirectly cooled by a cooler stream of fluid to condense that portion of the gas which can be held in a liquid state under substantially ambient conditions or temperature and pressure. The condensed liquid is then cycled through the heating step to further stabilize the hydrocarbons of the liquid.

The invention further contemplates that at least one separator vessel be provided ahead of the heat-treatment process for the oil well emulsion to stage the pressure reduction on the emulsion in separating the gaseous components. The liquid portion of the well stream is then heated and the liquefiable components of gas evolved are cycled through the heating step to further stabilize the hydrocarbons of the liquid and remove the water from the process.

The invention further contemplates that the water vapor portion of all gaseous components evolved in the heating step will be received by a passage which will keep the condensed water isolated from the clean oil and take it to a location which is a substantial distance below the surface of the clean oil and/ or into combination with the emulsion going to the heating step so it can join the other water separated from the well stream and removed from the process.

The invention further contemplates that fractions of all gaseous hydrocarbons evolved in the heating step will be brought into indirect heat-exchange with the oil well production to condense the fractions which can be held as a liquid at ambient conditions. A conduit will then bring the collected condensate fractions to the stream of production while keeping the condensate isolated from the clean oil produced. The production and condensate mixture is then taken to the heat-treating process so the condensed fractions may again be heated to further stabilize them.

The invention further contemplates flowing the oil well production through two indirect heat exchangers. The production will function as a cooling medium in each exchanger, condensing fractions from all gaseous hydrocarbons evolved from the heat treating of the production and cooling the clean oil produced by the treatment. At the same time, a collection location is provided for a V I 3,043,072

3 the fractions condensed and a conduit provided to carry them into combination with the production as it goes to the heat-treating process. This arrangement'provides a plurality. of cooling functions for the production and 'a fractionating cycle for all liquefiable hydrocarbons evolved as gas from the heat-treating of the production.

The invention further contemplates flowing the oil well production into the heating chamber of a treater vessel in which sufficient residence time is provided to thorough- 1y mix any chemical added and to permit stratification of the oil and emulsion in a strata and free water in a separate strata. A heat source is provided in the oil and emulsion strata to confine the direct heat transfer from the source to the oil and emulsion strata.

The invention further contemplates that the selective heating of the 'oil and emulsion strata will raise these well stream components to their highest temperature. directly. above the source of heat and evolved substantially all the hydrocarbon gas and water vapor, which will evolve as gas. The gas will be taken by'conduits into heat exchange with the cooler well stream, before the well stream is 'passed into the stratification chamber'to condense a portion of the gas and return that condensate to the well stream which is going to the heated strata and to a location a substantial distance below the surface of the clean oil produced by the process. Baflies are arranged to continually draw oil and emulsion from the, top of the heated strata and direct these components downwardly and then upwardly, through a coalescing section in the vessel.

Other objects, advantages and features of this invention will become 'more apparent to one skilled in the art upon consideration of written specification, appended claims, and the attached drawings, wherein:

z FIG. 1 is a diagrammatic, sectioned, elevation of an 'oil well emulsion treater embodying the present invention;

FIG. 2 is an elevation of another treater embodying other features of the invention;

FIG. 3 is an elevation of another treater embodying additional features of the invention; and

FIG, 4 is a diagrammatic, sectioned, elevation of an oil well emulsion: treater somewhat different from the treaters of FIGS. 1, 2 and 3 and embodying some of the features of the invention.

Referring to FIG. 1, numeral 1 designates an elongated cylindrical tank extending vertically, its upper end closed by a domed head 2 and its lower end closedby a dished bottom 3. The tank is set upon a suitablesupport 4 and has an internal, transverse, horizontal partition 5 near its upper end. This transverse partition 5 forms, with head 2, a gas separation chamber 6.

Separator 7 moved from the shell 1 as a unit. This arrangement facilitates cleaning and servicing the separator and replacing it with one having a different pressure'capacity. Liquid: conduit 14 is extended upward, from separator 10, through heat exchanger 20. V V

' Although not shown in FIG. 1, separator ltlis normally structures. However, these ranges must be understood to depend upon subjective characteristics of the well stream and the equipment available to process the well stream. 7

The pressure at which the treating in vessel-tank 1 is carried out may be in theorder of 10 to 15 lbs. per sq. in. If a high pressure separator, not shown in FIG. 1, is available, it may be operated within a range of 600 to 800 lbs. per sq. in. A general objective of staging the pressure reduction is to carry out each stage of reduction just below the base of the retrograde pressure range. There are points relative to the retrograde pressure range at which an optimum release of the lighter methane, ethane and propane gases can be brought about with a minimum release of the heavier hydrcarbons in the form of gas. In general, adding stages of pressure reduction at these points will produce larger quantities of hydrocarbon liquid available for the treating process.

An additional advantage in staging the pressure reduction ahead of the treating vessel 1 is found in lowered costs for the fabrication of the treating vessel 1 itself. With the higher pressures in the separators ahead of tank 1, tank 1 need only be as thick in wall size as required for retention of the well fluids at a low treating pressure.

With separator 10 mounted in the lower portion of 1 shell 1, an additional advantage is found in the heat exchange between the warm fluids within the shell 1 and the colder fluids of the well stream. When the entire heat balance requirements of thesystem have been properly considered the fluids of separator 10 may be protected from freezing, due to low ambient temperatures, by being warmed with the fluids of'tank 1.

Returning to a consideration of the immediate function of separator 10 on thewell stream, the well stream is seen to be spun and deflected by diverter structure 12 into its gaseous and liquid phases. So separated, the

gaseous phase is discharged through conduit 13 to a sales Separator 163 may serve a gas sales lien which operates at lbs. per sq. in. Back pressure valve 21 may be set to open at 60. lbs. per sq. in, being fully opened at 65 lbs. per sq. in. Under normal conditions of operation, there will be both a liquid and gas flow through separator 10, the gas pressure building up in separator 10 above 5Q lbs. so that continuous delivery through conduit 13, and its valve 15, will take place. The liquid level will rise in separator 10 and actuate float 16 to close valve 15 until thepressure in separator 10 reaches lbs. per sq. in. At 60 lbs. per sq. in. valve 21 will begin to open and the liquids will flow to the top of tank 1 if the 60 lbs.

.per sq. in. is high enough to overcome the hydraulic 1 head and the treating pressure held on treater tank 1.

expected to be part of. a complete system for staging the pressure reduction of the well stream from the wellhead to the treating process oftankl. Several pressure ranges may be recited to illustrate the relation between the 7 Should the liquid level in separator 10 continue to increase, valve 15 will be closed further, developing the pressure in separator 10 above 60 lbs. per sq. in. neces-- sary to flow the liquid phase to the separator section 6.

Shouldthe liquid level in separator 10 continue to rise and lift float 16 valve 15 will be closed and liquid will he positively-prevented from going out gas conduit 13. Should the liquids in separator 10 'decerase to a very smallamount, gas valve 15 will be opened wide so that gas will always be discharged through conduit 13 and normally fail to build the pressure up to the setting of valve 21' and thereby escape into the separator section 6 in the top of the treater.

H eat Exchanger 20 tubes telescoped within each other concentrically. Liquid conduit 14 is arranged as the inner tube.

Arranged concentrically about conduit 14 is conduit 22 which removes liquid from separation chamber 6 downwardly through heat exchanger 20. The liquids removed from separator 6 by conduit 22., are taken to a heat treating process in the lower part of vessel 1 and just above the location of separator 16.

Arranged concentrically about both conduit 14 and conduit 22 is conduit 23. Downcomer conduit 23 removes the clean oil produced by heat treating process within tank-vessel 1 and heat exchanges it with the well stream of conduit 22 to conserve heat introduced in the heat treating process.

Heat Exchanger 25 Conduit 14 is extended out of the top of the

other conduits

22 and 23 of heat exchanger 26 to connect with heat exchanger 25 mounted within separation chamber 6. Comparable to heat exchanger 2%, heat exchanger 25 is made up of three concentric tubes. Tube 26 constitutes the outer shell of heat exchanger 25 and receives conduit 14 at its lower end. Conduit 27 is connected to the upper end of tube 26 and to a diverter plate 28, mounted on the inner wall of chamber 6. This particular arrangement of tube 26, in heat exchanger 25, permits the indirect contact of the incoming well stream with all of the gaseous products developed by the subsequent heat treating of this same well stream within vessel 1. The liquids of conduit 14 are thus passed up through heat exchanger 25 and into diverter 28 to be spread out on the wall of the upper part of the shell of the treater vessel 1 in chamher 6. Gas is separated from the well stream by this action and carried out of the vessel 1 through a mist extractor structure 29 and outlet conduit 36.

As stated before tube 26 constitutes the outside shell of heat exchanger 25 in separation chamber 6. From within tube 26 another tube is concentrically telescoped Within a third tube in order to bring all gas evolved in the heat treatment of the liquid well stream into indirect contact with the liquids before these liquids are heat-treated. Specifically, tube 31 extends downwardly from heat exchanger 25, through transverse partition 5 to a point well below the surface of the clean oil produced by the process.

Telescoped up inside of tube 31 is tube 32 which brings the gases evolved directly from heat treating process up into exchanger 25. Holes 33 are provided in the Wall of tube 31, just below partition 5, to bring gaseous vapors developed above the surface of the clean oil up into separation chamber 6.

Just below heat exchanger 25, connected to conduit 31, is a conduit '34. Conduit 34 takes all or" the uncondensed vapor from both

conduits

31 and 32 through indirect heat exchange with the well stream liquids from diverter 28 which have collected in the bottom of chamber 6. After this heat exchange, the gases which are still not condensed are ejected into the gaseous space of chamber 6, passing out mist extractor 23 through conduit 36.

Heat exchanger 25 functions to bring all of the gaseous hydrocarbons and water vapor developed in the heat treating process of the well stream into indirect heat exchange contact with the relatively cool liquids of the well stream before the Well stream is taken to the heat treating process. As gaseous hydrocarbons and Water vapor rise within central heat exchange conduit 32, a portion of the products which can be liquefied condense out and fall back in conduit 32 or conduit 31. In either event, the water condensed is maintained consistently isolated from the clean oil produced by the heat treating process. This Water is removed to a point well below the surface of the clean oil and descends to the bottom of vessel 1 for removal through a conduit.

The hydrocarbons and water vapor which are not condensed as they rise within

conduits

31 and 32 continue to be cooled as they pass through conduit 34. Further condensation of these vapors occur and these liquids flow back down conduit 34 and conduit 32, remaining isolated from the clean oil. As these liquids are deposited well below the surface of the clean oil, the hydrocarbon distillate will join the clean oil and rise to the point of exit while the water will continue to descend for separate removal and not contaminate the clean oil product.

Conduit 34, functionally, is a continuation of the heat exchange surfaces of exchanger which continues the function of condensation by heat exchange with the liquids collected on the bottom of chamber 6. Finally, the gaseous products which have been stripped of all components which are storageable at ambient conditions, as liquid, are removed from gas outlet 30.

H eating Zone 41 Attention is now redirected to the well stream liquids collected on the bottom of chamber 6 and flowing down conduit 22. Conduit 22 liquids are introduced, by conduit 43', into a heating zone 41 in the lower portion of vessel ll, directly above separator 16. A firetube 42 is shown, representing a source of heat for zone 41. Firetube 42 may take any of several well known conventional forms. Conventionally, these firetubes are supplied the products of combustion of gas taken from gas outlet conduit 3i When gas outlet does not have sufficient as for this heating, another source of gas must be supplied.

Heating zone 41 is formed about firetube 42 by a hood 43 and bafiie 44. Hood 43 has a depending skirt, or lip, closely positioned to vertical baflle 44. Battle 44 is extended well below firetube 42 in order to form the heating zone 41 about firetube 42 which Will contain only emulsified oil and water to be directly heated by firetube 42.

Maintaining firetube 4-2 immersed in oil, Within heating zone 41, gives an opportunity for the thermal currents developed by the firetube to completely mix and roll the emulsion. This function would not be accomplished if the emulsion was simply passed up over the tube immersed in water. Thus the heat is applied to that portion of the Well stream where it is most needed to break the emulsion between oil and water. The free water is not heated and heat is not thereby wasted in heating the water.

A large portion of the hydrocarbon fractions and water which can be evolved in the heating process is driven from the well stream 'at the location above firetube 42 in zone 41 and passes up conduit 32 to heat exchanger 2-5. Only the upper, hottest, portions of the heated emulsion in zone 41 is removed to pass upwardly through the agglomerating section of the treater. The depending skirt or bafile of hood 43, and transverse bafile 44, are arranged to skim the uppermost layer of the emulsion in zone 41 and pass this heated emulsion downwardly and release it upwardly so that it will flow upwardly toward the agglomerating, or filter, section, while any solid foreign matter and water will flow downwardly to the bottom of the treater.

The emulsion heated in zone 41 is released from hood 43 only after it has attained the highest temperature possible by the firing of tube 42. This heated emulsion is completely prepared for treating by agglomerating section 45. The treating is then completed by the oil being coalesced and the water being coalesced within section 45. The clean oil produced is passed to a point above filter section 45 to collect in a body, and the water coalesced gravitates downwardly to be removed through water outlet conduit 46.

FIG. 2 is used to illustrate a treater quite similar to that shown in FIG. 1. A tank has a head 51 and bottom 52 with a support 53. A transverse partition 54 defines a separating chamber 55 in the upper end of the tank 50.

There is no relatively high pressuretseparator shown in the bottom of tank 50. If required, a separator similar to that'in FIG. 1 may be employed to receive the well stream and pass its liquids to inlet conduit 60.. Thus it 7 is that a separator similar to 10 of FIG. 1 need not be incorporated in the treater. However, if such a separator is not employed the advantages of its use are not realized.

Heat Exchanger 61 Inlet conduit 60 passes the liquids-of the well stream into separator chamber 55, after they pass through heat exchanger 61. Heat exchanger 61 provides

conduits

62 and 63 about conduit 60 in order to conserve the heat of the process by transferring a considerable portion of the heat from the clean oil produced to emulsion taken to the heat treating section of tank 50.

H eat Exclzanger 65 Heat exchanger 65 in separating chamber 55, is quite similar to heat exchanger in providing a means whereby the relatively cool incoming well stream can be used to cool all of the liquefiable components of the gases evolved from the heating process. Further, the structure of heat exchanger 65 correspondingly provides for keep- 7 ing liquids condensed by the cooling isolated from the clean oil productwhile talc'ng these liquids to a point where they can be released to separate into oil and water. The oil joins the clean oil product of the process while water is directed into combination with water developed during the heat treating.

. evolved from the coalescing section of the treater, above the hot clean oil product, it is desirable that the water vapor portion of this gas not be condensed and dropped into the clean 'oil as it leaves the treater. Bafile 66 is provided below partition 54 as an illustration of an insulating head which avoids condensation of this evolved gas at this point. The uncondensed gas flows into'holes 67 in conduit 68 where the condensate formed will be kept isolated from the clean oil and be carried to a point where the water can join the other water developed in treating and be disposed of without contaminating the clean oil.

Heating Zone 70 Conduit 62 is shown removing the liquids of separating chamber to heating zone70. In heating zone 70 the' emulsion of the well stream is held in a comparatively large body where it isfraised to its highest temperature in the process while being given a much longer retention time in the body than heretofore available in prior art structures. The advantage of 'this function of the large, isolated, heating zone has already been developed in describing the similar heating zone 41 of FIG. 1. r

The heated emulsion is continuously drawn from the top of the zone 70 and directed downwardly and then upwardly'toward the coalescing section. If any sand, or other foreign matter, has been carried to this point of. heated emulsion removal from the zone 70 the final'reversal of direction of its flow will tend to throw solid foreign matter downwardly from the heated emulsion. The heated emulsion will then rise upwardly through the coalescing section of the treater to collect in a clean body of oil.- The clean body of oil is removed from above coalescing section 71 through conduit 63 where the heat place. The gas. evolved above the clean oil is carried out holes 67 as previously described.

Referring to H6. 3,- there has been shown a treater tank 72 quite similar to the tanlevessels of the proceeding figures. A head 73 and a bottom 74 are provided as in the other structures; The entire tank rests on a support 75 and a transverse partition 76 provides the upper separation chamber 77. V V c Again, an integral high pressure separator is not disclosed as mounted in the bottom of tank 70. The well stream is brought to the treater through conduit 80 and passes through heat exchanger 81 which is quite similar to the heat exchangers'of FIGS. 1 and 2 In distinguishment from the preceding structures, conduit 80 does not pass through heat exchanger 81 and pass the well stream directly into separation chamber 77. Rather, a tube sheet 32 and a tube sheet 8 3 are provided across conduit 84 which conduit is concentric about con duit 8t A plurality of tubes 85 extend upward from the tube sheet 83 to terminate at tube sheet 86. The result is to form a heat exchanger between tube sheets 83 and 86 into which the well stream is passed on the tube side.

The heat exchanger, external of tank 72,.between dam sheets 83 and 86 brings the. well stream and substantially all the evolved gases of the heating process together for condensation of the liquefia'ble components therefrom. Both water vapor and; hydrocarbon fractions may be condensed and fall back to a point well below the surface of the clean oil. 7 However, some "condensation will also occur within the heat exchanger between dam sheets 83' and S6. The condensed liquids could, be removed to a point in the coalescing section, at least well below the clean oil surface. Conduit 87 is here provided to continually draw off these condensates and pass them into. conduit 84, below dam sheet 82, so that they will mix with the liquids of the well stream going to the heat treatment process in the lower part of vessel 72. This arrangement provides a recycling of the condensible hydrocarbons and water through the heat treating process, for disposal of the water and further stabilization of the hydrocarbons.

That portion of the gas which does not liquefy in the heat exchanger between dam sheets 83 and 86 is removed from the shell side of the heat exchanger by means of conduitflih Conduit 90 merely represents one means whereby these uncondensed gaseous products of the heat treating process are joined with those gaseous. products separated in chamber 77 to pass out of the tre'ater through 'is passed upward'through conduit 92.

Tray 94;

Gas 'evolvedfrom the coalescing section of the treater and collecting above the clean oil surface may contain water vapor which it would not be desirable 'to condense back into the clean oil product. Condensation can be avoided by insulating the gas from the cooled underside of partition 76. Tray 94- offers an alternate to insulation.

Tray 94 is provided beneath partition 76. with risers 9.5, whichpass the gas rising from the top of the clean oil up into contact with the cooled head 76. Condensate formed on partition 76 will fall'and collect on tray 94 and flow into conduit 93 through holes 916. Gas which does not condense'is drawn up conduit 93 through holes 97.

The gas from conduit 2 and the gas from conduit 93 is combined in conduit 98. if Conduit 98 passes these gases into, the shell side of the heat exchanger between dam sheets 83 and 86. Should condensation occur in either

conduit

92 or 93, the liquids will fall back into the heat: treating processwell below the clean oilsurface-while remaining completely isolated therefrom. No possibility-1 of contamination by condensed water ispossible.v "The condensates are either placed in the coalescing section of the .treater or are placed in the emulsion going into the heat treating process in the lower portion of the treater. In either event, cutting of the quality of the clean oil produced is avoided and placing the hydrocarbon fractions in the emulsion additionally provides for their continual restabilization.

The well stream passing out of the plurality of tubes 85 into the upper portion of conduit 84 above darn sheet 86 is spread on the internal walls of separation chamber 77 by diverter 100. The diverter 1% is placed near conduit 93 so that the liquids of the well stream discharged from diverter 100 will cool conduit 93 and condense the gases collected therein. The liquids fall into a collection above transverse partition 76 and are drawn into conduit 84 and downwardly into the lower part of tank 72.

Transverse partition 101 is part of a particular form of water knockout and emulsion spreader. A central hole 102 is provided in partition 101, about which two circular battles are concentrically arranged. The outer circular battle 103 is provided with a hole 194 near its juncture with partition 101 and on the side opposite the discharge point of emulsion from conduit 84. The inner, concentric, partition 1135 has serrations on its lower edge. The emulsion distributed under partition 101 is retarded and distributed in a strata by circular partition 103 and discharged from this strata through hole 104. Emulsion through the hole 104 is directed downwardly and then upwardly over the serrations of circular partition 1495. Free water which has been developed by the preheating in heat exchanger 81 and in the strata under partition 101, is started downwardly while the emulsion is flowed upwardly over firetube 106.

Firetube 196 is located beneath a hood 107 in an arrangement similar to the preceding drawings. Hood 107, with its depending skirt, and transverse bathe 108, provide all the advantages of the large capacity heating zone as described in connection with the prior structures.

The heated emulsion is drawn from beneath hood 1G7 and into coalescing section 109. The gas developed by this heating is drawn upwardly through conduit 92 for condensation as previously described. Clean oil above coalescing section 109 is drawn downwardly through heat exchanger 81 and out conduit 110.

Referring now to FIG. 4; there is shown a tank 120 with a domed head 121 and a dished bottom 122, all resting on a support 123.

No high pressure separator or external liquid-liquid heat exchanger is disclosed. These features can be combined with the structure, however, it is anticipated that a wide range of types of oil well production can be handled successfully without employing these features in this form of treater.

The oil Well production is brought into tank 120 through conduit 125. Conduit 125 places the well stream in heating zone 126, very similar to the heating zones of the preceding disclosures,

Hood 127, with depending skirt, is used to define heating zone 126, in co-operation with transverse bafiie 128. Flume 129 extends upwardly from hood 127 to carry ofi the majority of gaseous components developed by the direct heating of the well fluids in heating zone 126 by firetube 130.

The well stream flowing in at the bottom of the treater through conduit 125 drops its free water to the bottom of the treater. The oil and emulsion of the well stream is then heated in zone 126 with firetube 130 immersed in the emulsion and oil. The thermal currents created by this heating causes an agitation of the oil to remove entrained gas, and at the same time creates good chemical mixing and more even distribution of chemical in the oil to promote efficient treating. The gas developed is conducted up the center flume 129.

The gas going up fiume 129 is taken into a dome 131 1% mounted on the top of head 121. Baffies 132 break up any foam that may have been developed. Conduit 133 draws off the developed gas and fins 134 are mounted on conduit 133 to dissipate the heat from this gas and condense hydrocarbon fractions and Water Vapor from the gaseous mixture,

The condensed liquids in conduit 133 drop straight down to a point within the coalescing section of the treater, remaining isolated from the clean oil. The gas which is not liquefied passes out conduit 135 and gas outlet 136.

Any gas evolved above the clean oil collected above the coalescing section joins the fiume 12% gas and the mixture flows out gas outlet 136. The condensate iskept isolated from the clean oil by conduit 133 and drops to the coalescing section.

From the foregoing it will be seen that thisinvention is one well adapted to attain all of the ends and objects hereinabove set forth, together with other advantages which are obvious and which are inherent to the method and apparatus.

It will be understood that certain features and subcombinations are of utility and may be employed without reference to other features and subcom binations. This is contemplated by and is within the scope of the claims.

As many possible embodiments may be made of the invention without department from the scope thereof, it is to be understood that all matter herein set forth or shown in the accompanying drawings is to be interpreted as illustrative and not in a limiting sense.

The invention having been described, What is claimed 1s:

1. A system of treating oil Well production, including.

a heat source controlled to heat the production and break it into oil and Water and gas,

a collector for evolved gas directly above the heat source,

a first conduit from the collector for the evolved gas,

a coalescing section receiving the oil and emulsion prepared by the heater for coalescence,

a chamber for collecting the clean oil produced from the coalescence section,

a second conduit extending into the gas space above the clean oil in the clean oil chamber which removes the evolved gas from above the clean oil and maintains any Water condensed in the second conduit isolated from the clean oil in the clean oil chamber as the clean oil is produced from the chamber,

a third conduit connected to the first and second conduits for combining the gas of the first and second conduits,

a heat exchanger connected to the third conduit and bringing the production into heat exchange with the combined gas to condenser that portion of the combined gas which can be held in a liquid state under substantially ambient conditions,

and a fourth conduit for the condensate of the heat exchanger with which the condensate is removed from the heat exchanger and mixed with the production going to the heat source to further stabilize the hydrocarbons of the condensate.

2. A system of treating oil Well production, including a heat source which is controlled so it will heat the production and separate it into oil and water and a collector directly above the heat source for gas evolved by heating the production to the highest temperature it attains in the system,

a first conduit connected to the collector for removing the evolved gas from the collector,

a coalescing section receiving the production remaining in a liquid state as the production is withdrawn from the collector,

a chamber in which clean oil section is collected,

a first heat exchanger connected to the clean oil produced by the coalescing 11 chamber to bring the clean oil and production'ifi heat exchange with each other prior to the production beingiheat ed by the controlled heat source,

a second conduit connected to the gas space above the clean'oil in the clean oil chamber Which receives gas evolved from the clean oil, v a

a second heat exchanger connected to the first and second conduits to bring all the gaseous components evolved by the controlled heat source into heat exchange with the production prior to the production being heated by the controlled heat source,

a third conduit connected to the second conduit to receive water condensed in the second conduit and keep the water isolated from the clean oil produced by the coalescing section while returning the water to the coalescing section from where the water gravitates downwardly for disposal,

and a fourth conduit receiving the condensate of the second heat exchanger and placing the condensate into the production as it goes to the controlled heat source, whereby the hydrocarbons of the condensate are further stabilized.

3. The method of treating oil well production, comrsrng,

collecting the production into a volume sufiiciently large to permit stratification of the oil and emulsion into a strata and free water into a separate strata,

directing heat into the oil and emulsion strata which will evolve gas,

continuously withdrawing oil and emulsion from the heated strata as it is raised to a maximum temperature,

coalescing the oil and water of the oil and emulsion strata after it has been raised to the maximum temperature to produce clean oil,

condensing water and hydrocarbons from all vapors evolved above the surface of the coalesced oil,

condensing water and hydrocarbons from all vapors evolved from directly heating the oil and emulsion strata,

maintaining all the condensed Water and hydrocarbons from all these vapors isolated from the clean oil,

flowing a first portion of the isolated water and hydrocarbons beneath the surface of the clean oil,

and flowing the remainder of the isolated water and hydrocarbons to the large volume of collected production.

4. An oil well production treater, including,

a source of oil well production delivering production into the treater for heat treatment,

baflles within the treater providing a volume receiving the production and sufficiently large to permit stratification of the oil and emulsion into a strata and free water into'a separate strata,

a source of heat mounted in the oil and emulsion strata to direct heat into the strata which will evolve gas,

means for flowing the hottest portion of the strata of oil and emulsion from the large volume,

a coalescing section in the treater receiving the hottest portion of the strata of oil and emulsion to produce the clean oil asthe treater output,

means for condensing water and hydrocarbon from all vapors evolved above the surface of the coalesced oil, 7

means for condensing water and hydrocarbons from all vapors evolved from the directly heated oil and emulsion strata, V

and a conduit system for keeping all the condensed water and hydrocarbons isolated from the clean oil while carrying a first portion of the isolated water and hydrocarbons below the surface of the clean oil and the remaining condensates to the large volume of production. Y

5. A system for treating oil Well production, including,

a heat exchanger for receiving all a heat source controlled to heat the production and a chamber for collecting the clean oil produced from the coalescence section,

a second conduit extending upwards into the gas space above the clean oil in the clean oil chamber to remove the gas evolved from above the clean oil and extending downward a substantial distance below the clean oil surface to maintain any water condensed in the second conduit isolated from the clean oil in the clean oil chamber as the clean oil is produced from the chamber and take the water condensed in the conduit to a location a substantial distance below the a clean oil surface. 7 V

a third conduit connected to the first and second conduits for combining gas of the first and second conduits,

a heat exchanger connected to the third conduit and bringing the production into heat exchange with the combined gas to condense that portion of the combined gas which can be held in a liquid state under substantially ambient conditions, a

6. ,An oil well production treater including,

a source of oil Well production delivering production into the treater for heat treatement,

r a source of heat mounted within the treater for heating a coalescing section above the heat source and below the separator chamber above which a body of clean oil is produced as a product of the treater,

an insulation means between the gas space above the body of clean oil and the separator to keep the cooler fluid stream of production in the separator chamber from condensing the warmer gas evolved from the coalescing section,

the gas evolved from the coalescing section for cooling by the production before the production is passed to the source of heat,

and a conduit system for keeping all the condensed -water and hydrocarbons isolated from the clean oil While carrying a first portion of the isolated water and hydrocarbons below the surface of the clean oil and the remaining condensates to the large volume of production.

7. An oil well production treater including,

a source of heat mounted within the treater for heating the oil well production,

a separator chamber above the heat source receiving separator passing all the warmer gas evolved from the coalescing section into heat exchange with the separator chamber and collecting the condensate,

a first conduit system for receiving gases evolved immediately following heating of the production by the source of heat and those gases not condensed on the ment for restabilization of the hydrocarbons of the condensate.

References Cited in the file of this patent UNITED STATES PATENTS 2,528,032 Candler et a1 Oct. 31, 1950 2,765,917 Francis Oct. 9, 1956 2,948,352 Walker et a1. Aug. 9, 1960