CA2574244A1 - Hydrocarbon production system and method of use - Google Patents
Hydrocarbon production system and method of use Download PDFInfo
- Publication number
- CA2574244A1 CA2574244A1 CA002574244A CA2574244A CA2574244A1 CA 2574244 A1 CA2574244 A1 CA 2574244A1 CA 002574244 A CA002574244 A CA 002574244A CA 2574244 A CA2574244 A CA 2574244A CA 2574244 A1 CA2574244 A1 CA 2574244A1
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- Prior art keywords
- hydrocarbon
- subsurface
- production
- fluid
- compressed gas
- 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.)
- Abandoned
Links
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 175
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 175
- 239000004215 Carbon black (E152) Substances 0.000 title claims abstract description 171
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 160
- 238000000034 method Methods 0.000 title claims abstract description 22
- 239000012530 fluid Substances 0.000 claims abstract description 118
- 239000003129 oil well Substances 0.000 claims abstract description 26
- 239000000356 contaminant Substances 0.000 claims abstract description 20
- 239000011435 rock Substances 0.000 claims abstract description 7
- 239000012634 fragment Substances 0.000 claims abstract description 5
- 238000005086 pumping Methods 0.000 claims description 14
- 230000002250 progressing effect Effects 0.000 claims description 9
- 229920000297 Rayon Polymers 0.000 claims description 8
- 239000007787 solid Substances 0.000 claims description 5
- 238000009825 accumulation Methods 0.000 claims description 3
- 238000013022 venting Methods 0.000 claims description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 3
- 230000002028 premature Effects 0.000 claims description 2
- NIFIFKQPDTWWGU-UHFFFAOYSA-N pyrite Chemical compound [Fe+2].[S-][S-] NIFIFKQPDTWWGU-UHFFFAOYSA-N 0.000 claims description 2
- 229910052683 pyrite Inorganic materials 0.000 claims description 2
- 239000011028 pyrite Substances 0.000 claims description 2
- 230000003247 decreasing effect Effects 0.000 claims 1
- 238000001556 precipitation Methods 0.000 claims 1
- 239000007789 gas Substances 0.000 abstract description 79
- 239000000203 mixture Substances 0.000 abstract description 5
- 239000004576 sand Substances 0.000 abstract description 5
- 239000003673 groundwater Substances 0.000 abstract description 4
- -1 shale Substances 0.000 abstract description 3
- 230000000903 blocking effect Effects 0.000 abstract description 2
- 239000004927 clay Substances 0.000 abstract description 2
- 239000003245 coal Substances 0.000 abstract description 2
- 230000001376 precipitating effect Effects 0.000 abstract description 2
- 238000000926 separation method Methods 0.000 description 8
- 238000004891 communication Methods 0.000 description 6
- 239000003921 oil Substances 0.000 description 5
- 238000005299 abrasion Methods 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- 239000002184 metal Substances 0.000 description 3
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- 230000035508 accumulation Effects 0.000 description 2
- 239000010426 asphalt Substances 0.000 description 2
- 239000000295 fuel oil Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 241000237858 Gastropoda Species 0.000 description 1
- 239000003570 air Substances 0.000 description 1
- 239000011805 ball Substances 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 229910002092 carbon dioxide Inorganic materials 0.000 description 1
- 230000006837 decompression Effects 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 230000000750 progressive effect Effects 0.000 description 1
- 230000002459 sustained effect Effects 0.000 description 1
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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
- E21B43/122—Gas lift
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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)
- Jet Pumps And Other Pumps (AREA)
Abstract
The method of the present invention employs a subsurface production pump to displace hydrocarbon fluid, including any and all accompanying ground water and/or earthen contaminants, from the subterranean hydrocarbon reservoir depth of an oil well to surface storage and handling facilities via the subsurface production tubing, wellhead and surface flow line. As the subsurface production pump operates, compressed gas, or a mixture of compressed gases of sufficient volume and force is fed into the lower end of the subsurface production tubing in proximity to, or at a point above the subsurface production pump to mix into the hydrocarbon production fluid column.
The resultant and considerably reduced density of the subsurface hydrocarbon production fluid column provides a reduction of subsurface production pump loading with all types of subsurface production pumps, and an improvement of sucker rod fall time when sucker rod activated subsurface plunger pumps are employed. Due to the additional cubic volume of the injected compressed gas, the increased hydrocarbon production fluid and gas velocity within the subsurface production tubing and the surface flow line improves hydrocarbon fluid shear from the conduit walls and sucker rod surfaces, and prevents earthen contaminants such as sand, clay, shale, coal or other rock fragments, from precipitating, accumulating and blocking the flow of hydrocarbon production fluid within the subsurface production tubing and the surface flow line.
The resultant and considerably reduced density of the subsurface hydrocarbon production fluid column provides a reduction of subsurface production pump loading with all types of subsurface production pumps, and an improvement of sucker rod fall time when sucker rod activated subsurface plunger pumps are employed. Due to the additional cubic volume of the injected compressed gas, the increased hydrocarbon production fluid and gas velocity within the subsurface production tubing and the surface flow line improves hydrocarbon fluid shear from the conduit walls and sucker rod surfaces, and prevents earthen contaminants such as sand, clay, shale, coal or other rock fragments, from precipitating, accumulating and blocking the flow of hydrocarbon production fluid within the subsurface production tubing and the surface flow line.
Description
METHOD OF USE
BACKGROUND OF THE INVENTION
The purpose of the present invention is to provide an improved method 7 and an improved apparatus to displace light, medium, heavy or very viscose hydrocarbon fluid which may be contaminated with earthen solids and water, 9 from a subterranean hydrocarbon reservoir to a hydrocarbon production fluid storage tank or other handling facilities on ground surface, by means of oil 11 well production, especially in oil wells wherein currently used hydrocarbon production systems are mechanically incapable of sustained or economic 13 production.
The method of the present invention employs a subsurface production pump to displace hydrocarbon fluid, including any and all accompanying 17 ground water and/or earthen contaminants, from the subterranean hydrocarbon reservoir depth of an oil well to surface storage and handling 19 facilities via the subsurface production tubing, wellhead and surface flow line.
As the subsurface production pump operates, compressed gas, or a mixture 21 of compressed gases of sufficient volume and force is fed into the lower end of the subsurface production tubing in proximity to, or at a point above the 23 subsurface production pump to mix into the hydrocarbon production fluid column.
The resultant and considerably reduced density of the subsurface 1 hydrocarbon production fluid column provides a reduction of subsurface production pump loading with all types of subsurface production pumps, and 3 an improvement of sucker rod fall time when sucker rod activated subsurface plunger pumps are employed. Due to the additional cubic volume of the injected compressed gas, the increased hydrocarbon production fluid and gas velocity within the subsurface production tubing and the surface flow line 7 improves hydrocarbon fluid shear from the conduit walls and sucker rod surfaces, and prevents earthen contaminants such as sand, clay, shale, coal 9 or other rock fragments, from precipitating, accumulating, and blocking the flow of hydrocarbon production fluid within the subsurface production tubing 11 and the surface flow line.
Subterranean hydrocarbon reservoir characteristics and hydrocarbon fluid characteristics, may present problems wherein continuous or more 17 economical hydrocarbon production is difficult or not possible while employing current production systems including subsurface sucker rod driven plunger 19 pumps and progressive cavity pumps or other types of subsurface production pumps.
The more viscose hydrocarbons have a great tendency to adhere to 23 inner conduit walls and sucker rod surfaces, and also have very resistant fluid flow shear properties. Relatively clean hydrocarbon fluids having a temperature of 20 degree Centigrade and densities of 980 to 999 kg per cubic meter, being pumped to surface from a 600 meter deep oil well, may require 27 60% more pumping horsepower than when pumping the same volume of light hydrocarbon fluid having the same temperature from similar depths.
1 Sucker rod activated tubing liner or insert type subsurface production pumps are the mainstay of most oil fields around the world, and are very well 3 suited to the production of light and medium hydrocarbons and will often operate trouble free for several years. When used for the production of more viscose hydrocarbons such as heavy oil or bitumen, which may contain earthen contaminants, the sucker rods will often float on the downstroke and 7 must be slowed down to prevent pump jack and/or sucker rod damage.
Reduced daily production is thereby unavoidable.
If the light or viscose hydrocarbon fluid being produced contains 11 considerable amounts of earthen particulates, the earthen particulates may accumulate and cause fluid blockages within the subsurface production tubing 13 and surface flow line. When the accumulation of earthen particulates becomes too great, the sucker rods simply will not fall, or will not fall at an acceptable fall rate, through the column of hydrocarbon fluid and earthen materials, and production thereby fails, and well servicing is required. The 17 earthen particulates also cause extreme abrasion of the sucker rods and production tubing and premature failure of each, which eventually will require 19 replacement of each. Sucker rod and production tubing abrasion, wear and mechanical stress is greatly increased in oil wells that have high pumping 21 pressures and/or deviations off the vertical line due to drilling problems, or in slant, whip stocked or horizontal well bores.
Progressing cavity subsurface production pumps driven by sucker rods are more successful in the production of the more viscose hydrocarbons and are, to a degree, somewhat better able to cope with earthen particulates.
27 These pumps inherit all the problems associated with sucker rod use, are quickly destroyed when the well bore fluid is pumped off, or the rotors and 1 stators will be badly damaged when pumping rock fragments or pyrite balls or sand or sand slugs. They have a much shortened life and a much reduced 3 efficiency when pumping high fluid pressures and/or high fluid temperatures.
They also have a much shortened life when pumping high amounts of earthen particulates, especially water sand and rock fragments. Within many oil sands production wells, seizure of the sucker rods by accumulations of earthen 7 particulates packed within the subsurface production tubing string is a never ending problem that may occur daily. Electrically driven submersible 9 progressing cavity pumps enjoy some use in the effort to eliminate friction and abrasion caused sucker rod and production tubing wear, but are still prone to 11 the other limitations of progressing cavity pumps.
13 A great number of oil wells producing light or heavy oil or bitumen from earthen particulate laden subterranean hydrocarbon reservoirs, employing any of the subsurface production pumps available to-day, would be rendered technically or economically inoperable without the very expensive and 17 frequent backup services of auxiliary equipment including pressure trucks, flush-by rigs, well servicing rigs or coiled tubing rigs to remove accumulated 19 earthen particle build-up and/or blockages from the oil well's well bore, subsurface production pump, subsurface production tubing and surface flow 21 line. Frequent replacement of subsurface components due to excessive metal to metal wear, especially in the presence of abrasive produced earthen 23 particulates, presents considerable replacement cost in addition to the economic loss of sales revenue due to oil well down time.
A percentage of such oil wells present ongoing problems that seem 27 unsolvable. After spending substantial amounts of time, money and fruitless effort, such oil wells are sooner or later considered to be mechanically or 1 economically not viable, and are usually sold or abandoned.
BACKGROUND OF THE INVENTION
The purpose of the present invention is to provide an improved method 7 and an improved apparatus to displace light, medium, heavy or very viscose hydrocarbon fluid which may be contaminated with earthen solids and water, 9 from a subterranean hydrocarbon reservoir to a hydrocarbon production fluid storage tank or other handling facilities on ground surface, by means of oil 11 well production, especially in oil wells wherein currently used hydrocarbon production systems are mechanically incapable of sustained or economic 13 production.
The method of the present invention employs a subsurface production pump to displace hydrocarbon fluid, including any and all accompanying 17 ground water and/or earthen contaminants, from the subterranean hydrocarbon reservoir depth of an oil well to surface storage and handling 19 facilities via the subsurface production tubing, wellhead and surface flow line.
As the subsurface production pump operates, compressed gas, or a mixture 21 of compressed gases of sufficient volume and force is fed into the lower end of the subsurface production tubing in proximity to, or at a point above the 23 subsurface production pump to mix into the hydrocarbon production fluid column.
The resultant and considerably reduced density of the subsurface 1 hydrocarbon production fluid column provides a reduction of subsurface production pump loading with all types of subsurface production pumps, and 3 an improvement of sucker rod fall time when sucker rod activated subsurface plunger pumps are employed. Due to the additional cubic volume of the injected compressed gas, the increased hydrocarbon production fluid and gas velocity within the subsurface production tubing and the surface flow line 7 improves hydrocarbon fluid shear from the conduit walls and sucker rod surfaces, and prevents earthen contaminants such as sand, clay, shale, coal 9 or other rock fragments, from precipitating, accumulating, and blocking the flow of hydrocarbon production fluid within the subsurface production tubing 11 and the surface flow line.
Subterranean hydrocarbon reservoir characteristics and hydrocarbon fluid characteristics, may present problems wherein continuous or more 17 economical hydrocarbon production is difficult or not possible while employing current production systems including subsurface sucker rod driven plunger 19 pumps and progressive cavity pumps or other types of subsurface production pumps.
The more viscose hydrocarbons have a great tendency to adhere to 23 inner conduit walls and sucker rod surfaces, and also have very resistant fluid flow shear properties. Relatively clean hydrocarbon fluids having a temperature of 20 degree Centigrade and densities of 980 to 999 kg per cubic meter, being pumped to surface from a 600 meter deep oil well, may require 27 60% more pumping horsepower than when pumping the same volume of light hydrocarbon fluid having the same temperature from similar depths.
1 Sucker rod activated tubing liner or insert type subsurface production pumps are the mainstay of most oil fields around the world, and are very well 3 suited to the production of light and medium hydrocarbons and will often operate trouble free for several years. When used for the production of more viscose hydrocarbons such as heavy oil or bitumen, which may contain earthen contaminants, the sucker rods will often float on the downstroke and 7 must be slowed down to prevent pump jack and/or sucker rod damage.
Reduced daily production is thereby unavoidable.
If the light or viscose hydrocarbon fluid being produced contains 11 considerable amounts of earthen particulates, the earthen particulates may accumulate and cause fluid blockages within the subsurface production tubing 13 and surface flow line. When the accumulation of earthen particulates becomes too great, the sucker rods simply will not fall, or will not fall at an acceptable fall rate, through the column of hydrocarbon fluid and earthen materials, and production thereby fails, and well servicing is required. The 17 earthen particulates also cause extreme abrasion of the sucker rods and production tubing and premature failure of each, which eventually will require 19 replacement of each. Sucker rod and production tubing abrasion, wear and mechanical stress is greatly increased in oil wells that have high pumping 21 pressures and/or deviations off the vertical line due to drilling problems, or in slant, whip stocked or horizontal well bores.
Progressing cavity subsurface production pumps driven by sucker rods are more successful in the production of the more viscose hydrocarbons and are, to a degree, somewhat better able to cope with earthen particulates.
27 These pumps inherit all the problems associated with sucker rod use, are quickly destroyed when the well bore fluid is pumped off, or the rotors and 1 stators will be badly damaged when pumping rock fragments or pyrite balls or sand or sand slugs. They have a much shortened life and a much reduced 3 efficiency when pumping high fluid pressures and/or high fluid temperatures.
They also have a much shortened life when pumping high amounts of earthen particulates, especially water sand and rock fragments. Within many oil sands production wells, seizure of the sucker rods by accumulations of earthen 7 particulates packed within the subsurface production tubing string is a never ending problem that may occur daily. Electrically driven submersible 9 progressing cavity pumps enjoy some use in the effort to eliminate friction and abrasion caused sucker rod and production tubing wear, but are still prone to 11 the other limitations of progressing cavity pumps.
13 A great number of oil wells producing light or heavy oil or bitumen from earthen particulate laden subterranean hydrocarbon reservoirs, employing any of the subsurface production pumps available to-day, would be rendered technically or economically inoperable without the very expensive and 17 frequent backup services of auxiliary equipment including pressure trucks, flush-by rigs, well servicing rigs or coiled tubing rigs to remove accumulated 19 earthen particle build-up and/or blockages from the oil well's well bore, subsurface production pump, subsurface production tubing and surface flow 21 line. Frequent replacement of subsurface components due to excessive metal to metal wear, especially in the presence of abrasive produced earthen 23 particulates, presents considerable replacement cost in addition to the economic loss of sales revenue due to oil well down time.
A percentage of such oil wells present ongoing problems that seem 27 unsolvable. After spending substantial amounts of time, money and fruitless effort, such oil wells are sooner or later considered to be mechanically or 1 economically not viable, and are usually sold or abandoned.
5 More particularly, in accordance with one aspect of this invention, there is provided a subsurface production pump connected to the lower end of a 7 compressed gas conveyance tubing system, with said compressed gas conveyance tubing system extending from a source of compressed gas at 9 surface, down into and returning up out of an oil well having a subterranean hydrocarbon reservoir, oil well casing and casing perforations that provide 11 hydrocarbon fluid inflow from the subsurface hydrocarbon reservoir into the well bore, the improvement comprising a compressed gas conveyance tubing 13 system employing a subsurface production pump and including;
a source of compressed gas; a wellhead; conduit means to connect the source of compressed gas to the wellhead; a subsurface compressed gas feed tubing string extending from a connection at the 17 wellhead to the approximate subsurface hydrocarbon reservoir depth of the well bore; a subsurface hydrocarbon production tubing string extending 19 from the approximate subsurface hydrocarbon reservoir depth, through the wellhead to a surface flow line connection; a surface flow line with a 21 connection at one end to the subsurface hydrocarbon production tubing string, and a connection at the other end to a hydrocarbon production fluid storage 23 tank; a hydrocarbon production fluid storage tank or other fluid handling facility(s) ; means to vent gas from the hydrocarbon production fluid storage tank; a subsurface production pump connected to the lower subsurface end of the compressed gas conveyance tubing system; means for fluid 27 communication from the subsurface production pump into the subsurface hydrocarbon production tubing string; means for gas communication from 1 the subsurface compressed gas feed tubing string into the subsurface hydrocarbon production tubing string; means to recover hydrocarbon fluid 3 and contaminants.
In another aspect of the present invention, there is provided an improvement in a method of displacing various grades of hydrocarbon fluid, 7 which may be contaminated with earthen contaminants and ground water, from subterranean hydrocarbon reservoirs to surface storage, by means of oil 9 well production, which method includes the steps of;
Flooding hydrocarbon fluid from the subterranean hydrocarbon 11 reservoir into the well bore; pumping hydrocarbon production fluid and it's contaminants from the well bore, into and through the subsurface 13 hydrocarbon production tubing string, through the wellhead, into and through the surface flow line, and into the hydrocarbon production fluid storage tank or other handling facility(s) at surface;
feeding compressed gas of sufficient volume and pressure from a 17 source at surface, by conduit means, into and through the wellhead, into and through the subsurface compressed gas feed tubing string, into and through 19 the compressed gas communication port, into and through the subsurface hydrocarbon production tubing string, through the wellhead, into and through 21 the surface flow line, and into the hydrocarbon production fluid storage tank or other handling facility(s) at surface; mixing compressed gas, hydrocarbon 23 fluid and it's contaminants within the subsurface hydrocarbon production tubing string; permitting the compressed gas to decompress within the subsurface hydrocarbon production tubing string and surface flow line;
providing a means to separate produced hydrocarbon fluid and gas at 27 surface; venting gas from within the hydrocarbon production fluid storage tank or other handling facility(s) at surface; providing means to recover 1 hydrocarbon fluid and contaminants from the hydrocarbon production storage tank or other handling facility(s) at surface; continuing the production 3 cycle;.
In the present system and method, any suitable subsurface production pump including progressing cavity pumps, plunger pumps or electric 7 submersible pumps, may be used to pump grades of light to very viscose hydrocarbon fluid which may contain substantial amounts of solid earthen 9 contaminants and/or ground water, from the well bore into the hydrocarbon production storage tank or other handling facility(s) at surface.
Use is made of the fact that a compressed gas feed of sufficient 13 volume and pressure can be injected into the lower end of the subsurface production tubing string in order to provide certain mechanical effects and advantages throughout the entire hydrocarbon pumping apparatus.
17 As the compressed gas is fed into the lower end of the subsurface hydrocarbon production tubing string at a point preferably, but not necessarily, 19 located just above the operating subsurface production pump, the preferably continuous feed of compressed gas is mixed and combined with hydrocarbon 21 production fluid. As the mixture advances upwards to the surface storage facility(s) at an accelerated fluid velocity due to the additional volume of 23 injected gas, the gas decompresses proportionally, throughout the entire subsurface hydrocarbon production fluid column, resulting in a subsurface hydrocarbon production fluid column of much lighter weight or density above the subsurface production pump, the advantages being a considerably 27 reduced load on the subsurface production pump, reduced mechanical strain and wear on all components throughout the entire pumping apparatus, and an 1 increased hydrocarbon production fluid velocity within the subsurface hydrocarbon production tubing string and surface flow line. The higher fluid 3 velocity improves viscose fluid flow properties through conduits and improves the fluid flow entrainment of solids though conduits. If sucker rod driven subsurface plunger pumps are used, sucker rod fall time is very much reduced due the much reduced density of the hydrocarbon production fluid 7 column, and less horsepower is required to lift the sucker rods during the upstroke. If sucker rod driven progressing cavity pumps are used, 9 considerably less horse power is required to drive the sucker rod string due to the reduced work load on the progressing cavity pump, and there will be a 11 considerable reduction of hydrocarbon fluid drag on the rotating sucker rods.
13 The minimal or optimal mechanical effects and advantages achieved by the method of the present invention may be calculated by, and are dependant upon the volume of compressed gas being fed into the lower end of the subsurface hydrocarbon production tubing string. By sufficiently 17 increasing the volume of compressed gas being fed into the lower end of the subsurface hydrocarbon production tubing string at a point in proximity to, or 19 above the subsurface production pump, the subsurface production pump output of hydrocarbon fluid and earthen contaminants combine with, and 21 become part of, the resulting high velocity hydrocarbon fluid and gas stream flowing through the subsurface hydrocarbon production tubing string, through 23 the wellhead, into and through the surface flow line and into the hydrocarbon production storage tank or other handling facility(s) at surface. When thus displacing the hydrocarbon fluid and it's contaminants from the output end the subsurface production pump to surface storage, all components of this 27 hydrocarbon production pumping method and apparatus operate within a state of it's best mechanical efficiency. Herein, less horsepower is required, 1 less equipment stress and wear is present, and the subsurface production pump operates at maximum efficiency with minimal effort and wear.
In carrying out the present invention, any desired mixture of gases, or any practical gas of convenience such as steam, natural gas, air, or carbon dioxide, may be compressed and employed as the compressed gas of choice.
The subsurface compressed gas feed tubing string and the subsurface 9 hydrocarbon production tubing string may be suspended from or through the wellhead parallel to each other within the well bore, or one of the subsurface 11 tubing strings may be more conveniently placed inside the other and one tubing string can exit the wellhead through a metal connector or suitable pack-13 off to simplify installation. By employing a hollow sucker rod string, the said hollow sucker rod string may also serve as the subsurface hydrocarbon production tubing string or as the subsurface compressed gas feed tubing string.
The greater amount of gas may be removed from the hydrocarbon fluid 19 as the hydrocarbon fluid is fed into the hydrocarbon production fluid storage tank. The optional gas separation conduit illustrated in Figure 3, preferably 21 should have an inside diameter of sufficient size to conduct the hydrocarbon fluid, by gravity means, to a lower level of the hydrocarbon production fluid 23 storage tank without having excessive spillage of hydrocarbon fluid out the top of the gas separation conduit. In selecting the inside diameter of the gas separation conduit, consideration should be given to the hydrocarbon fluid's expected input volume, temperature and viscosity.
In cases where two or more oil wells are closely positioned, as on a 1 pad with multiple oil wells, one gas compressor of sufficient capacity may be very efficiently used to supply the compressed gas feed for two or more oil 3 wells. With the subsurface production pump of each oil well operating continuously, the one gas compressor of sufficient capacity may inject 5 sufficient amounts of compressed gas into the lower ends of two or more subsurface hydrocarbon production fluid columns intermittently to achieve the 7 desired effect(s) within each oil well. A programmable valve controller or other means may be used to open and close valves as required to repetitively cycle 9 compressed gas to each of the oil wells as required. Alternatively, the gas compressor may feed two or more oil wells simultaneously by employing 11 compressed gas flow dividers or other means to direct accurate volumes of compressed gas to each oil well.
Figure 2 illustrates the apparatus of the present invention wherein the sucker rods also serve as the subsurface hydrocarbon production tubing string, employing a plunger type subsurface production pump which expels it's 17 hydrocarbon fluid output directly into the lower end of the subsurface hydrocarbon production tubing string. If an alternate choice of subsurface 19 production pump is configured quite differently, it may be necessary to install the alternate subsurface production pump so as to expel it's hydrocarbon fluid 21 output firstly into the subsurface compressed gas feed tubing string, and then permit the hydrocarbon fluid output to flow into the subsurface hydrocarbon 23 production tubing string through compressed gas communication port 18.
The preferred choice of subsurface production pump for the method of the present invention is the tubing liner plunger pump. By comparison, it is 27 much less expensive, much more durable, has a greatly extended service life, and may be used for cold primary or thermally stimulated production. If 1 progressing cavity pumps are used, the number of progressing cavity stages should be reduced in order to make the passing of earthen solids less 3 damaging to the rotors and stators.
BRIEF DESCRIPTION OF THE DRAWINGS
7 Having thus generally described the invention, reference will now be made to the accompanying drawings illustrating preferred embodiments in 9 which;
Figure 1 is a schematic illustration of a typical prior art system to 11 displace hydrocarbon fluid from a subterranean hydrocarbon reservoir to surface storage or handling facility(s).
Figure 2 is a schematic illustration outlining the method of the present invention to displace hydrocarbon fluid from a subterranean hydrocarbon reservoir to surface storage or handling facility(s).
Figure 3 illustrates one simple method to separate gas from 19 hydrocarbon fluid.
23 Referring initially to Figure 1, a typical conventional oil well system includes a production casing indicated by reference numeral 8 which is placed into the earth. Within the casing 8 there is provided a subsurface production tubing string 12 which is basically a length of coiled tubing or lengths of 27 conduit coupled together from a connection from wellhead 6 to subsurface 1 production pump 17. The system may also include what is commonly known as sucker rods 10. In use, hydrocarbon fluid 13 is fed by means of 3 subterranean hydrocarbon reservoir 16 pressure into well bore 9 through casing perforations 14 and pumped from well bore 9 by subsurface production pump 17, into and through subsurface hydrocarbon production tubing 12, into and through wellhead 6, into and through surface flow line 21, into and 7 through optional surface check valve 20 and into hydrocarbon production fluid storage tank 22. Valve 7 is provided to vent casing gas. Optional surface 9 check valve 20 may be provided to prevent stored hydrocarbon fluid 13 from back-flowing from hydrocarbon production fluid storage tank 22 into 11 subsurface hydrocarbon production tubing string 12. Vent 23 is provided to vent gas from storage tank 22. The sucker rod drive at surface is not shown.
According to the present invention, as illustrated in Figure 2, the conventional oil well production system is modified to displace hydrocarbon fluid from an oil well's subterranean hydrocarbon reservoir to a hydrocarbon 17 production fluid storage tank or other handling facilities at surface by following the steps of;
19 providing a compressed gas conveyance tubing system extending from a source of compressed gas at ground surface, through the wellhead and 21 down the well bore to the subterranean hydrocarbon reservoir depth and returning up out of the well bore, through the welihead and into the 23 hydrocarbon production fluid storage tank at surface, with said compressed gas conveyance tubing system including;
a source of compressed gas 1; conduit 2; wellhead 6; casing gas vent 7; casing 8; well bore 9; subsurface compressed gas feed 27 tubing string 11; subsurface hydrocarbon production tubing string 12;
hydrocarbon fluid 13; casing perforations 14; subterranean 1 hydrocarbon reservoir 16; subsurface production pump 17; compressed gas communication port 18; optional surface check valve 20; surface flow line 3 21; hydrocarbon production fluid storage tank 22; storage tank gas vent 23; optional gas separation conduit 24; gap 25;
flooding hydrocarbon fluid 13 from subterranean hydrocarbon reservoir 16 through casing perforations 14 into well bore 9, by means of subterranean 7 hydrocarbon reservoir 16 pressure; pumping hydrocarbon production fluid 13 from well bore 9 by means of subsurface production pump 17, into and 9 through subsurface hydrocarbon production tubing string 12, through wellhead 6, into and through surface flow line 21, into and through optional 11 gas separation conduit 24 if it is employed, and into hydrocarbon production fluid storage tank 22 ;
13 feeding compressed gas 1 from a source at surface, into and through conduit 2, into and through wellhead 6, into and through subsurface compressed gas feed tubing string 11, into and through compressed gas communication port 18, into and through subsurface hydrocarbon production 17 tubing string 12, through wellhead 6, into and through surface flow line 21, into and through optional gas separation conduit 24 if it is employed, and into 19 hydrocarbon production fluid storage tank 22 ;
permitting the compressed gas 1 to mix with hydrocarbon production 21 fluid 13, within subsurface hydrocarbon production tubing string 12, and achieve all possible decompression therein; permitting the resulting 23 elevated stream velocity of the combined cubic volumes of decompressing gas, hydrocarbon fluid and contaminants, to flow through subsurface hydrocarbon production tubing string 12, through wellhead 6, into and through surface flow line 21, into and through optional gas separation conduit 24 if it is 27 employed, and into hydrocarbon production fluid storage tank 22 ;
causing the high density of the column of hydrocarbon fluid 13, flowing 1 through subsurface hydrocarbon production tubing string 12, to be reduced to a choice of any desired density during and throughout normal operating time, 3 by supplying and mixing the volume of gas 1 as required, into the column of hydrocarbon fluid 13;
optionally separating the mixture of compressed gas 1 and hydrocarbon fluid 13 by feeding hydrocarbon fluid 13 from the output end of 7 conduit 21, through gap 25, into the open top end of and through optional gas separation conduit 24;
9 venting gas 1 from hydrocarbon production fluid storage tank 22, through storage tank gas vent 23 to atmosphere or other gas handling facility;
11 optionally preventing stored hydrocarbon fluid 13 from back-flowing from hydrocarbon production fluid storage tank 22 into subsurface production 13 tubing string 12 by means of optional surface check valve 20 ; operating the hydrocarbon production system ; recovering hydrocarbon fluid 13 and contaminants from the hydrocarbon production fluid storage tank 22 or other handling facility(s).
a source of compressed gas; a wellhead; conduit means to connect the source of compressed gas to the wellhead; a subsurface compressed gas feed tubing string extending from a connection at the 17 wellhead to the approximate subsurface hydrocarbon reservoir depth of the well bore; a subsurface hydrocarbon production tubing string extending 19 from the approximate subsurface hydrocarbon reservoir depth, through the wellhead to a surface flow line connection; a surface flow line with a 21 connection at one end to the subsurface hydrocarbon production tubing string, and a connection at the other end to a hydrocarbon production fluid storage 23 tank; a hydrocarbon production fluid storage tank or other fluid handling facility(s) ; means to vent gas from the hydrocarbon production fluid storage tank; a subsurface production pump connected to the lower subsurface end of the compressed gas conveyance tubing system; means for fluid 27 communication from the subsurface production pump into the subsurface hydrocarbon production tubing string; means for gas communication from 1 the subsurface compressed gas feed tubing string into the subsurface hydrocarbon production tubing string; means to recover hydrocarbon fluid 3 and contaminants.
In another aspect of the present invention, there is provided an improvement in a method of displacing various grades of hydrocarbon fluid, 7 which may be contaminated with earthen contaminants and ground water, from subterranean hydrocarbon reservoirs to surface storage, by means of oil 9 well production, which method includes the steps of;
Flooding hydrocarbon fluid from the subterranean hydrocarbon 11 reservoir into the well bore; pumping hydrocarbon production fluid and it's contaminants from the well bore, into and through the subsurface 13 hydrocarbon production tubing string, through the wellhead, into and through the surface flow line, and into the hydrocarbon production fluid storage tank or other handling facility(s) at surface;
feeding compressed gas of sufficient volume and pressure from a 17 source at surface, by conduit means, into and through the wellhead, into and through the subsurface compressed gas feed tubing string, into and through 19 the compressed gas communication port, into and through the subsurface hydrocarbon production tubing string, through the wellhead, into and through 21 the surface flow line, and into the hydrocarbon production fluid storage tank or other handling facility(s) at surface; mixing compressed gas, hydrocarbon 23 fluid and it's contaminants within the subsurface hydrocarbon production tubing string; permitting the compressed gas to decompress within the subsurface hydrocarbon production tubing string and surface flow line;
providing a means to separate produced hydrocarbon fluid and gas at 27 surface; venting gas from within the hydrocarbon production fluid storage tank or other handling facility(s) at surface; providing means to recover 1 hydrocarbon fluid and contaminants from the hydrocarbon production storage tank or other handling facility(s) at surface; continuing the production 3 cycle;.
In the present system and method, any suitable subsurface production pump including progressing cavity pumps, plunger pumps or electric 7 submersible pumps, may be used to pump grades of light to very viscose hydrocarbon fluid which may contain substantial amounts of solid earthen 9 contaminants and/or ground water, from the well bore into the hydrocarbon production storage tank or other handling facility(s) at surface.
Use is made of the fact that a compressed gas feed of sufficient 13 volume and pressure can be injected into the lower end of the subsurface production tubing string in order to provide certain mechanical effects and advantages throughout the entire hydrocarbon pumping apparatus.
17 As the compressed gas is fed into the lower end of the subsurface hydrocarbon production tubing string at a point preferably, but not necessarily, 19 located just above the operating subsurface production pump, the preferably continuous feed of compressed gas is mixed and combined with hydrocarbon 21 production fluid. As the mixture advances upwards to the surface storage facility(s) at an accelerated fluid velocity due to the additional volume of 23 injected gas, the gas decompresses proportionally, throughout the entire subsurface hydrocarbon production fluid column, resulting in a subsurface hydrocarbon production fluid column of much lighter weight or density above the subsurface production pump, the advantages being a considerably 27 reduced load on the subsurface production pump, reduced mechanical strain and wear on all components throughout the entire pumping apparatus, and an 1 increased hydrocarbon production fluid velocity within the subsurface hydrocarbon production tubing string and surface flow line. The higher fluid 3 velocity improves viscose fluid flow properties through conduits and improves the fluid flow entrainment of solids though conduits. If sucker rod driven subsurface plunger pumps are used, sucker rod fall time is very much reduced due the much reduced density of the hydrocarbon production fluid 7 column, and less horsepower is required to lift the sucker rods during the upstroke. If sucker rod driven progressing cavity pumps are used, 9 considerably less horse power is required to drive the sucker rod string due to the reduced work load on the progressing cavity pump, and there will be a 11 considerable reduction of hydrocarbon fluid drag on the rotating sucker rods.
13 The minimal or optimal mechanical effects and advantages achieved by the method of the present invention may be calculated by, and are dependant upon the volume of compressed gas being fed into the lower end of the subsurface hydrocarbon production tubing string. By sufficiently 17 increasing the volume of compressed gas being fed into the lower end of the subsurface hydrocarbon production tubing string at a point in proximity to, or 19 above the subsurface production pump, the subsurface production pump output of hydrocarbon fluid and earthen contaminants combine with, and 21 become part of, the resulting high velocity hydrocarbon fluid and gas stream flowing through the subsurface hydrocarbon production tubing string, through 23 the wellhead, into and through the surface flow line and into the hydrocarbon production storage tank or other handling facility(s) at surface. When thus displacing the hydrocarbon fluid and it's contaminants from the output end the subsurface production pump to surface storage, all components of this 27 hydrocarbon production pumping method and apparatus operate within a state of it's best mechanical efficiency. Herein, less horsepower is required, 1 less equipment stress and wear is present, and the subsurface production pump operates at maximum efficiency with minimal effort and wear.
In carrying out the present invention, any desired mixture of gases, or any practical gas of convenience such as steam, natural gas, air, or carbon dioxide, may be compressed and employed as the compressed gas of choice.
The subsurface compressed gas feed tubing string and the subsurface 9 hydrocarbon production tubing string may be suspended from or through the wellhead parallel to each other within the well bore, or one of the subsurface 11 tubing strings may be more conveniently placed inside the other and one tubing string can exit the wellhead through a metal connector or suitable pack-13 off to simplify installation. By employing a hollow sucker rod string, the said hollow sucker rod string may also serve as the subsurface hydrocarbon production tubing string or as the subsurface compressed gas feed tubing string.
The greater amount of gas may be removed from the hydrocarbon fluid 19 as the hydrocarbon fluid is fed into the hydrocarbon production fluid storage tank. The optional gas separation conduit illustrated in Figure 3, preferably 21 should have an inside diameter of sufficient size to conduct the hydrocarbon fluid, by gravity means, to a lower level of the hydrocarbon production fluid 23 storage tank without having excessive spillage of hydrocarbon fluid out the top of the gas separation conduit. In selecting the inside diameter of the gas separation conduit, consideration should be given to the hydrocarbon fluid's expected input volume, temperature and viscosity.
In cases where two or more oil wells are closely positioned, as on a 1 pad with multiple oil wells, one gas compressor of sufficient capacity may be very efficiently used to supply the compressed gas feed for two or more oil 3 wells. With the subsurface production pump of each oil well operating continuously, the one gas compressor of sufficient capacity may inject 5 sufficient amounts of compressed gas into the lower ends of two or more subsurface hydrocarbon production fluid columns intermittently to achieve the 7 desired effect(s) within each oil well. A programmable valve controller or other means may be used to open and close valves as required to repetitively cycle 9 compressed gas to each of the oil wells as required. Alternatively, the gas compressor may feed two or more oil wells simultaneously by employing 11 compressed gas flow dividers or other means to direct accurate volumes of compressed gas to each oil well.
Figure 2 illustrates the apparatus of the present invention wherein the sucker rods also serve as the subsurface hydrocarbon production tubing string, employing a plunger type subsurface production pump which expels it's 17 hydrocarbon fluid output directly into the lower end of the subsurface hydrocarbon production tubing string. If an alternate choice of subsurface 19 production pump is configured quite differently, it may be necessary to install the alternate subsurface production pump so as to expel it's hydrocarbon fluid 21 output firstly into the subsurface compressed gas feed tubing string, and then permit the hydrocarbon fluid output to flow into the subsurface hydrocarbon 23 production tubing string through compressed gas communication port 18.
The preferred choice of subsurface production pump for the method of the present invention is the tubing liner plunger pump. By comparison, it is 27 much less expensive, much more durable, has a greatly extended service life, and may be used for cold primary or thermally stimulated production. If 1 progressing cavity pumps are used, the number of progressing cavity stages should be reduced in order to make the passing of earthen solids less 3 damaging to the rotors and stators.
BRIEF DESCRIPTION OF THE DRAWINGS
7 Having thus generally described the invention, reference will now be made to the accompanying drawings illustrating preferred embodiments in 9 which;
Figure 1 is a schematic illustration of a typical prior art system to 11 displace hydrocarbon fluid from a subterranean hydrocarbon reservoir to surface storage or handling facility(s).
Figure 2 is a schematic illustration outlining the method of the present invention to displace hydrocarbon fluid from a subterranean hydrocarbon reservoir to surface storage or handling facility(s).
Figure 3 illustrates one simple method to separate gas from 19 hydrocarbon fluid.
23 Referring initially to Figure 1, a typical conventional oil well system includes a production casing indicated by reference numeral 8 which is placed into the earth. Within the casing 8 there is provided a subsurface production tubing string 12 which is basically a length of coiled tubing or lengths of 27 conduit coupled together from a connection from wellhead 6 to subsurface 1 production pump 17. The system may also include what is commonly known as sucker rods 10. In use, hydrocarbon fluid 13 is fed by means of 3 subterranean hydrocarbon reservoir 16 pressure into well bore 9 through casing perforations 14 and pumped from well bore 9 by subsurface production pump 17, into and through subsurface hydrocarbon production tubing 12, into and through wellhead 6, into and through surface flow line 21, into and 7 through optional surface check valve 20 and into hydrocarbon production fluid storage tank 22. Valve 7 is provided to vent casing gas. Optional surface 9 check valve 20 may be provided to prevent stored hydrocarbon fluid 13 from back-flowing from hydrocarbon production fluid storage tank 22 into 11 subsurface hydrocarbon production tubing string 12. Vent 23 is provided to vent gas from storage tank 22. The sucker rod drive at surface is not shown.
According to the present invention, as illustrated in Figure 2, the conventional oil well production system is modified to displace hydrocarbon fluid from an oil well's subterranean hydrocarbon reservoir to a hydrocarbon 17 production fluid storage tank or other handling facilities at surface by following the steps of;
19 providing a compressed gas conveyance tubing system extending from a source of compressed gas at ground surface, through the wellhead and 21 down the well bore to the subterranean hydrocarbon reservoir depth and returning up out of the well bore, through the welihead and into the 23 hydrocarbon production fluid storage tank at surface, with said compressed gas conveyance tubing system including;
a source of compressed gas 1; conduit 2; wellhead 6; casing gas vent 7; casing 8; well bore 9; subsurface compressed gas feed 27 tubing string 11; subsurface hydrocarbon production tubing string 12;
hydrocarbon fluid 13; casing perforations 14; subterranean 1 hydrocarbon reservoir 16; subsurface production pump 17; compressed gas communication port 18; optional surface check valve 20; surface flow line 3 21; hydrocarbon production fluid storage tank 22; storage tank gas vent 23; optional gas separation conduit 24; gap 25;
flooding hydrocarbon fluid 13 from subterranean hydrocarbon reservoir 16 through casing perforations 14 into well bore 9, by means of subterranean 7 hydrocarbon reservoir 16 pressure; pumping hydrocarbon production fluid 13 from well bore 9 by means of subsurface production pump 17, into and 9 through subsurface hydrocarbon production tubing string 12, through wellhead 6, into and through surface flow line 21, into and through optional 11 gas separation conduit 24 if it is employed, and into hydrocarbon production fluid storage tank 22 ;
13 feeding compressed gas 1 from a source at surface, into and through conduit 2, into and through wellhead 6, into and through subsurface compressed gas feed tubing string 11, into and through compressed gas communication port 18, into and through subsurface hydrocarbon production 17 tubing string 12, through wellhead 6, into and through surface flow line 21, into and through optional gas separation conduit 24 if it is employed, and into 19 hydrocarbon production fluid storage tank 22 ;
permitting the compressed gas 1 to mix with hydrocarbon production 21 fluid 13, within subsurface hydrocarbon production tubing string 12, and achieve all possible decompression therein; permitting the resulting 23 elevated stream velocity of the combined cubic volumes of decompressing gas, hydrocarbon fluid and contaminants, to flow through subsurface hydrocarbon production tubing string 12, through wellhead 6, into and through surface flow line 21, into and through optional gas separation conduit 24 if it is 27 employed, and into hydrocarbon production fluid storage tank 22 ;
causing the high density of the column of hydrocarbon fluid 13, flowing 1 through subsurface hydrocarbon production tubing string 12, to be reduced to a choice of any desired density during and throughout normal operating time, 3 by supplying and mixing the volume of gas 1 as required, into the column of hydrocarbon fluid 13;
optionally separating the mixture of compressed gas 1 and hydrocarbon fluid 13 by feeding hydrocarbon fluid 13 from the output end of 7 conduit 21, through gap 25, into the open top end of and through optional gas separation conduit 24;
9 venting gas 1 from hydrocarbon production fluid storage tank 22, through storage tank gas vent 23 to atmosphere or other gas handling facility;
11 optionally preventing stored hydrocarbon fluid 13 from back-flowing from hydrocarbon production fluid storage tank 22 into subsurface production 13 tubing string 12 by means of optional surface check valve 20 ; operating the hydrocarbon production system ; recovering hydrocarbon fluid 13 and contaminants from the hydrocarbon production fluid storage tank 22 or other handling facility(s).
Claims (5)
1. A method of displacing light, medium or very viscose hydrocarbon fluid which may contain solid earthen contaminants and water, from the subterranean hydrocarbon reservoir of an oil well to a hydrocarbon production fluid storage tank or other handling facilities at ground surface, by means of an oil well, a compressed gas conveyance tubing system and a subsurface production pump, comprising the steps of;
constructing a compressed gas conveyance tubing system extending from a source of compressed gas at surface, through the wellhead and down the well bore to the approximate subterranean hydrocarbon reservoir depth of the well bore and returning up out of the well bore, through the wellhead and into a hydrocarbon production fluid storage tank or other handling facilities at ground surface; connecting a subsurface production pump to the lower end of the compressed gas conveyance tubing system, including means to activate said subsurface production pump;
flooding hydrocarbon fluid from the subterranean hydrocarbon reservoir by means of subterranean hydrocarbon reservoir pressure, through the casing perforations and into the well bore; pumping hydrocarbon fluid from the well bore into and through the subsurface hydrocarbon production tubing string, wellhead and surface flow line, and into the hydrocarbon fluid storage tank or other handling facilities at surface;
feeding a sufficient volume and pressure of compressed gas from a source at surface, through the compressed gas conveyance tubing system, and into the hydrocarbon fluid storage tank or other handling facilities at surface; separating gas and hydrocarbon fluid therein;
venting gas from the hydrocarbon production fluid storage tank or other handling facilities; continuing the hydrocarbon production system's production cycle; recovering hydrocarbon fluid and contaminants from the hydrocarbon production fluid storage tank or other facilities at ground surface.
constructing a compressed gas conveyance tubing system extending from a source of compressed gas at surface, through the wellhead and down the well bore to the approximate subterranean hydrocarbon reservoir depth of the well bore and returning up out of the well bore, through the wellhead and into a hydrocarbon production fluid storage tank or other handling facilities at ground surface; connecting a subsurface production pump to the lower end of the compressed gas conveyance tubing system, including means to activate said subsurface production pump;
flooding hydrocarbon fluid from the subterranean hydrocarbon reservoir by means of subterranean hydrocarbon reservoir pressure, through the casing perforations and into the well bore; pumping hydrocarbon fluid from the well bore into and through the subsurface hydrocarbon production tubing string, wellhead and surface flow line, and into the hydrocarbon fluid storage tank or other handling facilities at surface;
feeding a sufficient volume and pressure of compressed gas from a source at surface, through the compressed gas conveyance tubing system, and into the hydrocarbon fluid storage tank or other handling facilities at surface; separating gas and hydrocarbon fluid therein;
venting gas from the hydrocarbon production fluid storage tank or other handling facilities; continuing the hydrocarbon production system's production cycle; recovering hydrocarbon fluid and contaminants from the hydrocarbon production fluid storage tank or other facilities at ground surface.
2. A method of significantly reducing the operating load upon the subsurface production pump and prime mover, comprising the steps of;
providing the apparatus and method of Claim 1; ensuring that the compressed gas fed and mixed into the hydrocarbon fluid column flowing to surface storage through the subsurface hydrocarbon production tubing string and surface flow line is of sufficient volume to decompress and expand therein, to a degree that sufficiently displaces and reduces the density of the said hydrocarbon fluid column above the subsurface production pump.
providing the apparatus and method of Claim 1; ensuring that the compressed gas fed and mixed into the hydrocarbon fluid column flowing to surface storage through the subsurface hydrocarbon production tubing string and surface flow line is of sufficient volume to decompress and expand therein, to a degree that sufficiently displaces and reduces the density of the said hydrocarbon fluid column above the subsurface production pump.
3. A method of significantly decreasing the sucker rod fall time of subsurface reciprocating plunger pumps, comprising the steps of;
providing the method and apparatus of Claim 1; ensuring that the compressed gas fed and mixed into the hydrocarbon fluid column flowing to surface storage through the subsurface hydrocarbon production tubing string and surface flow line is of sufficient volume to decompress and expand therein, to a degree that sufficiently displaces and reduces the density of the said hydrocarbon fluid column, as to permit unimpeded lowering of the sucker rods and subsurface pump plunger through the said hydrocarbon fluid column.
providing the method and apparatus of Claim 1; ensuring that the compressed gas fed and mixed into the hydrocarbon fluid column flowing to surface storage through the subsurface hydrocarbon production tubing string and surface flow line is of sufficient volume to decompress and expand therein, to a degree that sufficiently displaces and reduces the density of the said hydrocarbon fluid column, as to permit unimpeded lowering of the sucker rods and subsurface pump plunger through the said hydrocarbon fluid column.
4. A method to eliminate the precipitation and accumulation of earthen particulates or small rocks or sharp edged rock fragments or pyrite balls within the subsurface production tubing string and surface flow line, while displacing hydrocarbon fluid containing such earthen contaminants from the output end of the subsurface production pump of an oil well to a hydrocarbon production fluid storage tank or other handling facilities at ground surface, comprising the steps of;
providing the apparatus and method of Claim 1; ensuring that the compressed gas fed and mixed into the hydrocarbon fluid column flowing to surface storage through the subsurface hydrocarbon production tubing string and surface flow line is of sufficient volume and pressure to permit the resulting enhanced velocity of the stream of combined cubic volumes of hydrocarbon fluid, earthen contaminants and decompressed gas, to flow from the subsurface production pump to the hydrocarbon production fluid storage tank or other handling facilities at surface.
providing the apparatus and method of Claim 1; ensuring that the compressed gas fed and mixed into the hydrocarbon fluid column flowing to surface storage through the subsurface hydrocarbon production tubing string and surface flow line is of sufficient volume and pressure to permit the resulting enhanced velocity of the stream of combined cubic volumes of hydrocarbon fluid, earthen contaminants and decompressed gas, to flow from the subsurface production pump to the hydrocarbon production fluid storage tank or other handling facilities at surface.
5. A method to significantly reduce premature wear and failure of progressing cavity subsurface production pumps caused by pumping high hydrocarbon fluid pressures, or by pumping hydrocarbon fluid containing earthen particulates or small rocks, while displacing hydrocarbon fluid containing such earthen contaminants from the subterranean hydrocarbon reservoir of an oil well to a hydrocarbon production fluid storage tank or other handling facilities at ground surface, comprising the steps of;
providing the apparatus and method of Claim 2.
providing the apparatus and method of Claim 2.
Priority Applications (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002574244A CA2574244A1 (en) | 2007-01-09 | 2007-01-09 | Hydrocarbon production system and method of use |
| US11/788,241 US20080164034A1 (en) | 2007-01-09 | 2007-04-20 | Hydrocarbon production system and method of use |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002574244A CA2574244A1 (en) | 2007-01-09 | 2007-01-09 | Hydrocarbon production system and method of use |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2574244A1 true CA2574244A1 (en) | 2008-07-09 |
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| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002574244A Abandoned CA2574244A1 (en) | 2007-01-09 | 2007-01-09 | Hydrocarbon production system and method of use |
Country Status (2)
| Country | Link |
|---|---|
| US (1) | US20080164034A1 (en) |
| CA (1) | CA2574244A1 (en) |
Families Citing this family (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2011041572A1 (en) * | 2009-09-30 | 2011-04-07 | Conocophillips Company | Double string pump for hydrocarbon wells |
| CA2775107C (en) * | 2009-09-30 | 2016-07-12 | Conocophillips Company | Slim hole production system |
| CN103601280B (en) * | 2013-12-04 | 2015-01-21 | 中国环境科学研究院 | Groundwater organic pollutant restoration device and method |
| CN103613199B (en) * | 2013-12-04 | 2015-02-25 | 中国环境科学研究院 | Restoring device for ammonia nitrogen polluted underground water |
| US11739618B2 (en) * | 2018-02-23 | 2023-08-29 | Extract Management Company, Llc | Processes for increasing hydrocarbon production |
Family Cites Families (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| FR2565576B1 (en) * | 1984-06-06 | 1989-12-22 | Petroles Cie Francaise | WATER DEAERATION PROCESS |
| US5431222A (en) * | 1994-01-10 | 1995-07-11 | Corpoven, S.A. | Apparatus for production of crude oil |
| US6209641B1 (en) * | 1999-10-29 | 2001-04-03 | Atlantic Richfield Company | Method and apparatus for producing fluids while injecting gas through the same wellbore |
-
2007
- 2007-01-09 CA CA002574244A patent/CA2574244A1/en not_active Abandoned
- 2007-04-20 US US11/788,241 patent/US20080164034A1/en not_active Abandoned
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