CA2511119A1 - Hydrocarbon production system and method of use - Google Patents
Hydrocarbon production system and method of use Download PDFInfo
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- CA2511119A1 CA2511119A1 CA002511119A CA2511119A CA2511119A1 CA 2511119 A1 CA2511119 A1 CA 2511119A1 CA 002511119 A CA002511119 A CA 002511119A CA 2511119 A CA2511119 A CA 2511119A CA 2511119 A1 CA2511119 A1 CA 2511119A1
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- Prior art keywords
- hydrocarbon
- subsurface
- compressed gas
- fluid
- well
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- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 341
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 341
- 239000004215 Carbon black (E152) Substances 0.000 title claims abstract description 337
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 223
- 238000000034 method Methods 0.000 title claims abstract description 66
- 239000012530 fluid Substances 0.000 claims abstract description 292
- 238000003860 storage Methods 0.000 claims abstract description 113
- 238000010926 purge Methods 0.000 claims abstract description 21
- 239000000356 contaminant Substances 0.000 claims abstract description 14
- 239000003673 groundwater Substances 0.000 claims abstract description 6
- 239000007789 gas Substances 0.000 claims description 273
- 239000003129 oil well Substances 0.000 claims description 53
- 238000013022 venting Methods 0.000 claims description 25
- 239000011435 rock Substances 0.000 claims description 18
- 239000012634 fragment Substances 0.000 claims description 15
- 238000009825 accumulation Methods 0.000 claims description 12
- 230000035508 accumulation Effects 0.000 claims description 12
- NIFIFKQPDTWWGU-UHFFFAOYSA-N pyrite Chemical compound [Fe+2].[S-][S-] NIFIFKQPDTWWGU-UHFFFAOYSA-N 0.000 claims description 12
- 229910052683 pyrite Inorganic materials 0.000 claims description 12
- 239000011028 pyrite Substances 0.000 claims description 12
- 238000004891 communication Methods 0.000 claims description 11
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 10
- 239000003245 coal Substances 0.000 claims description 9
- 238000005086 pumping Methods 0.000 claims description 9
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 8
- 239000004576 sand Substances 0.000 claims description 6
- 238000012546 transfer Methods 0.000 claims description 6
- 229910052751 metal Inorganic materials 0.000 claims description 4
- 239000002184 metal Substances 0.000 claims description 4
- 239000003345 natural gas Substances 0.000 claims description 4
- 230000003247 decreasing effect Effects 0.000 claims description 2
- 238000010438 heat treatment Methods 0.000 claims 1
- 238000000926 separation method Methods 0.000 description 11
- 229920000297 Rayon Polymers 0.000 description 7
- 239000000463 material Substances 0.000 description 7
- 230000005484 gravity Effects 0.000 description 6
- 238000005553 drilling Methods 0.000 description 5
- 239000003921 oil Substances 0.000 description 5
- 238000013461 design Methods 0.000 description 4
- 238000005299 abrasion Methods 0.000 description 3
- 238000009434 installation Methods 0.000 description 3
- 239000000203 mixture Substances 0.000 description 3
- 230000002250 progressing effect Effects 0.000 description 3
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- 241000237858 Gastropoda Species 0.000 description 2
- 239000010426 asphalt Substances 0.000 description 2
- 230000006835 compression Effects 0.000 description 2
- 238000007906 compression Methods 0.000 description 2
- 239000000295 fuel oil Substances 0.000 description 2
- 239000002245 particle Substances 0.000 description 2
- 238000001556 precipitation Methods 0.000 description 2
- 230000002028 premature Effects 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 235000014676 Phragmites communis Nutrition 0.000 description 1
- RTAQQCXQSZGOHL-UHFFFAOYSA-N Titanium Chemical compound [Ti] RTAQQCXQSZGOHL-UHFFFAOYSA-N 0.000 description 1
- 239000003570 air Substances 0.000 description 1
- 239000011805 ball Substances 0.000 description 1
- 230000005587 bubbling Effects 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 229910002092 carbon dioxide Inorganic materials 0.000 description 1
- ZPUCINDJVBIVPJ-LJISPDSOSA-N cocaine Chemical compound O([C@H]1C[C@@H]2CC[C@@H](N2C)[C@H]1C(=O)OC)C(=O)C1=CC=CC=C1 ZPUCINDJVBIVPJ-LJISPDSOSA-N 0.000 description 1
- 230000006837 decompression Effects 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 238000003780 insertion Methods 0.000 description 1
- 230000037431 insertion Effects 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000003027 oil sand Substances 0.000 description 1
- 239000013618 particulate matter Substances 0.000 description 1
- -1 pebbles Substances 0.000 description 1
- 239000002244 precipitate Substances 0.000 description 1
- 230000001376 precipitating effect Effects 0.000 description 1
- 230000000750 progressive effect Effects 0.000 description 1
- 230000005855 radiation Effects 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 230000002459 sustained effect Effects 0.000 description 1
- 239000010936 titanium Substances 0.000 description 1
- 229910052719 titanium Inorganic materials 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
Landscapes
- 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)
- Filling Or Discharging Of Gas Storage Vessels (AREA)
Abstract
The method of the present invention provides a means to intake hydrocarbon fluid, including any accompanying ground water or earthen contaminants, into the subsurface lower end of a tubing system. Compressed gas is then used to purge the hydrocarbon fluid from within the tubing system to a hydrocarbon production fluid storage tank or other handling facility at surface. Other than hydrocarbon fluid and gas movement, the ball of a subsurface intake valve is the production system's only moving subsurface component.
Description
METHOD OF USE
BACKGROUND OF THE INVENTION
The purpose of the method of the present invention is to provide an 7 improved method and an improved apparatus to displace light, medium, heavy or viscose hydrocarbon fluid from subterranean hydrocarbon reservoirs 9 to a hydrocarbon production fluid storage tank or other handling facilities on ground surface, by means of oil well production, including oil wells wherein ali I1 currently used hydrocarbon production systems are mechanically incapable of sustained or economic production.
The method of the present invention provides a means to intake L5 hydrocarbon fluid, including any accompanying ground water or earthen contaminants, into the subsurface lower end of a tubing system. Compressed 17 gas is then used to purge the hydrocarbon fluid from within the tubing system to a hydrocarbon production fluid storage tank or other handling facility at 19 surface. Other than hydrocarbon fluid and gas movement, the ball of a subsurface intake valve is the production system's only moving subsurface 21 component. A titanium subsurface intake valve is commonly available and has a much extended service life even when displacing hydrocarbons 23 containing very high volumes of earthen materials including pyrite balls, rock and coal fragments, ground water, fine or course water sand or oil sand. The 25 possibility of such earthen materials accumulating within or causing blockages within the subsurface production tubing or surface flow line is most improbable, as there is no way to prevent the increased velocity of hydrocarbon fluid from entraining and carrying such earthen solids through the 3 subsurface production tubing and surface flow line to surface storage during the oil welt production operation. The method is also useful in displacing hydrocarbon fluid from well-bores that deviate off the vertical due to drilling problems or intentional deviations caused in drilling slant, whipstocked or 7 horizontal oil wells.
Subterranean hydrocarbon reservoir characteristics, hydrocarbon fluid 11 characteristics, drilling problems or the well-bore design within some oil wells may present problems wherein continuous or more economical hydrocarbon 13 production is difficult or not possible while employing current production systems including subsurface sucker rod driven plunger pumps and progressive cavity pumps or other types of subsurface production pumps.
Sucker rod activated tubing liner or insert type subsurface production 17 pumps are the mainstay of most oil fields around the world, and are very well suited to the production of light and medium hydrocarbons and will often 19 operate trouble free for several years. When used for the production of more viscose hydrocarbons, heavy oil or bitumen, the sucker rods will often float on 21 the downstroke and must be slowed down to prevent pump jack and sucker rod damage. If the hydrocarbon fluid contains considerable amounts of 23 earthen particulates, the earthen particulates may accumulate and cause blockages within the subsurface production tubing and surface flow line.
When the accumulation of earthen particulates becomes too great, the sucker rods simply will not fall at an acceptable fall rate, through the column of 27 hydrocarbon and earthen materials, production thereby fails, and well servicing is required. The earthen particulates also cause extreme abrasion of 1 the sucker rods and production tubing and premature failure of each, which requires replacement of each. Sucker rod and production tubing abrasion, 3 wear and mechanical stress is greatly increased in oil wells that have deviations off the vertical line due to drilling problems, or in slant, whipstocked or horizontal well-bores.
7 Progressing cavity subsurface production pumps driven by sucker rods are more successful in the production of the more viscose hydrocarbons and 9 are, to a degree, somewhat better able to cope with earthen particulates.
These pumps inherit all the problems associated with sucker rod use, are 1 I quickly destroyed when the well-bore fluid is pumped off or the rotors and stators will be badly damaged when pumping rock fragments or pyrite balls or 13 sand slugs. They have a much shortened life when pumping high amounts of earthen particulates, especially water sand. Within many oilsands production wells, seizure of the sucker rods by accumulations of earthen particulates packed within the subsurface production tubing string is a never ending 17 problem that may occur daily. The rubber stator component of the progressing cavity subsurface production pump is easily damaged by sand 19 slugs, rock or coal fragments, pebbles, pyrite balls or the high pumping pressure encountered when accumulations of earthen particulates begin to 21 block the flow of hydrocarbon production within the subsurface production tubing or surface flow line.
A great number of oil wells producing heavy oil or bitumen from earthen particulate laden subterranean hydrocarbon reservoirs would be rendered technically or economically inoperable without the very expensive 27 and frequent backup services of auxiliary equipment including pressure trucks, flush-by rigs, well servicing rigs or coiled tubing rigs to remove accumulated earthen particle build-up andlor blockages from the oil well's well-bore, subsurface production pump, subsurface production tubing. and surface flow line. Frequent replacement of subsurface components due to excessive metal to metal wear andlor metal wear due to the presence of abrasive produced earthen particulates within slant, horizontal, vertical or deviated well-bores presents considerable replacement cost in addition to the economic loss of 7 sales revenue due to oil well down time.
9 Within a horizontal well-bore it would be advantageous to land a sucker rod activated subsurface production pump within or below the dog-leg.
11 This is not usually practical due to the sharp production tubing curve, or dog-leg, wherein the sucker rods must rotate or reciprocate, causing excessive 13 wear, fatigue and very rapid failure of sucker rods and/or subsurface production tubing. Horizontal oil wells having subsurface production pumps 15 placed within or above the well-bore's dog-leg often have a problem with earthen particulates precipitating from the hydrocarbon fluid being drawn to 17 the subsurface production pump and accumulating within the horizontal section of the well-bore and within the dog- legged section of the well-bore.
19 Such precipitated accumulations continue to increase in volume until the flow of hydrocarbon fluid from the subterranean hydrocarbon reservoir is blocked 21 from the intake of the subsurface production pump, and hydrocarbon production cannot be restarted until the earthen particulates are removed from 23 the well-bore.
25 Commonly, very considerable amounts of earthen particulates precipitate from the hydrocarbon fluid, after being drawn into the subsurface 27 production pump and accumulate within the subsurface production tubing string andlor surface flow line. Eventually, precipitated earthen particulate accumulations may cause production failure wherein production cannot be restarted until the earthen particulates are removed from the subsurface 3 production tubing. The problem of earthen particle precipitation within tubulars is greatly increased when water production of 18% or greater 5 accompanies the hydrocarbon fluid. New subsurface progressing cavity pump service life or operating time within such oil wells can often be as short as a 7 day or two. If such oil wells do not clean up after spending substantial amounts of time, money and fruitless effort, such oil wells are sooner or later 9 considered to be mechanically or economically not viable, and are usually sold or abandoned.
SUMMARY OF THE INVENTION
13 More particularly, in accordance with one aspect of this invention, there is provided a compressed gas conveyance tubing system extending from a source of compressed gas at surface, down into and returning up out of an oil well having a subterranean hydrocarbon reservoir, oil well casing and casing 17 perforations that provide hydrocarbon fluid inflow from the subsurface hydrocarbon reservoir into the well-bore, the improvement comprising a 19 compressed gas conveyance tubing system including;
a source of compressed gas; a wellhead; conduit means to 21 connect the source of compressed gas to the wellhead; a subsurface compressed gas feed tubing string extending from a connection at the 23 wellhead to the approximate subsurface hydrocarbon reservoir depth of the well-bore; a subsurface production tubing string extending from the approximate subsurface hydrocarbon reservoir depth, through the wellhead to a surface flow line connection; a surface flow line with a connection at one 27 end to the subsurface production tubing string, and a connection at the other end to a hydrocarbon production fluid storage tank; a hydrocarbon production fluid storage tank; means to vent gas from the hydrocarbon production fluid storage tank; a subsurface intake valve connected to the lower subsurface end of the compressed gas conveyance tubing system;
means for fluid communication through the subsurface intake valve into the subsurface production tubing string and the subsurface compressed gas feed tubing string; means for fluid and gas communication through the 7 subsurface compressed gas feed tubing string into the subsurface production tubing string; valve means to vent gas from the subsurface production 9 tubing string; valve means to vent gas from the subsurface compressed gas feed tubing string;
In another aspect of the present invention, there is provided an 13 improvement in a method of displacing various grades of hydrocarbon fluid from subterranean hydrocarbon reservoirs to surface storage by means of oil 15 well production, which method includes the steps of;
Flooding hydrocarbon fluid from the subterranean hydrocarbon 17 reservoir into the well-bore; evacuating or venting gas from within the subsurface section of the compressed gas conveyance tubing system;
19 flooding hydrocarbon fluid from the weN-bore through a subsurface intake valve and into the lower subsurface end of the compressed gas conveyance 21 tubing system; closing the subsurface intake valve to contain the hydrocarbon fluid within the lower subsurface end of the compressed gas 23 conveyance tubing system;
purging hydrocarbon fluid contained within the lower subsurface end of 25 the compressed gas conveyance tubing system into a hydrocarbon production fluid storage tank at surface by means of feeding compressed gas from a 27 source at surface, through the compressed gas conveyance tubing system and into the hydrocarbon production fluid storage tank or other handling facility on surface; repeating the cycle; providing a means to separate hydrocarbon fluid and gas; providing means to recover hydrocarbon fluid from the hydrocarbon production fluid storage tank or other handling facility at surface.
In the present system and method, in order to repetitively cycle the 7 hydrocarbon production system through the production cycle, employ optional operating modes, and apply the use of optional devices, it is recommended 9 that a preferably programabfe or other suitable gas valve controller is employed to activate the gas valves as required, to repetitively direct the 11 production system through it's operating modes and cycles.
13 The subsurface compressed gas feed tubing string and the subsurface production tubing string are vented of gas when necessary, by means of gas 15 venting valves at surface, allowing well-bore fluid head pressure and/or optional vacuum created within the subsurface compressed gas conveyance 17 tubing system by an optional vacuum pump at surface, to flood hydrocarbon fluid from the well-bore, into and through the subsurface intake valve and into 19 the lower subsurface end of the compressed gas conveyance tubing system.
The subsurface intake valve is then closed by gravity or other means, to trap 21 the hydrocarbon fluid therein.
The hydrocarbon fluid trapped within the subsurface compressed gas 23 feed tubing string and subsurface production tubing string is purged, or forced by means of gas displacement, up the subsurface production tubing string, 25 through the optional surface check valve, into and through the surface flow line, and into the hydrocarbon production fluid storage tank or other handling 27 facilities at surface. Optional modes and devices, as will be described later, may be incorporated into the present system.
As gas is compressed by the gas compressor in order to purge hydrocarbon fluid from the subsurface compressed gas conveyance tubing system to surface storage, much of the heat therein generated is carried by the compressed gas, into and through the subsurface compressed gas conveyance tubing system and may be used to heat the hydrocarbon fluid contained therein, by means of close contact, conduction or radiation between 7 the heated subsurface compressed gas tubing string and the subsurface production tubing string. The heat transfer process may be readily 9 understood by studying Figure 2, and is very useful in making viscose hydrocarbon fluid less viscose, and subsequently reduces the required 11 horsepower output of the gas compressor's prime mover and the gas compression required to purge the hydrocarbon fluid contained within the 13 subsurface compressed gas conveyance tubing system to surface storage.
The heat transfer method further serves to provide a small saving in the 15 amount of energy required to heat the hydrocarbon fluid within the surface hydrocarbon production fluid storage tank.
In the present system and method, use is made of the fact that a 19 compressed gas feed of sufficient volume and pressure can be employed to purge fluid volumes at considerable velocities through horizontal, vertical or 21 inclined conduits. The increased fluid velocity additionally provides increased viscose hydrocarbon fluid shear properties and decreased fluid flow friction 23 factors within the conduits. The fluid velocity, during a normal production cycle, also provides a hydrocarbon fluid carrier stream to entrain and carry 25 precipitated earthen particulate matter and rock fragments from the subterranean reservoir depth of the oil well, up the subsurface production 27 tubing string, through the surface flow line and into a hydrocarbon production fluid storage tank or other handling facilities at surface.
ft may be realized that the production apparatus of the present 3 invention does not have sucker rods, or any moving subsurface components other than the ball of a subsurface intake valve, therefore extreme or mild sucker rod tensite stress and wear and abrasion between the none-existing sucker rods and the production tubing string is eliminated. Because there are 7 no sucker rods, the method of the present invention is useful within oil wells that have any type of deviation from the vertical, such as well-bores that are 9 vertical, vertical with drilling deviations, slant, whipstocked or horizontal. The method encourages insertion of the subsurface lower end of the compressed 11 gas conveyance tubing system into and through the dog-legged section of a horizontal well-bore in order to achieve hydrocarbon fluid extraction directly 13 from the horizontal section of the well-bore. This advantage eliminates the precipitation and accumulation of earthen particulates that would otherwise accumulate and solidly plug the dog-legged section and entry section of the horizontal well-bore. By means of the compressed gas fed through the 17 compressed gas conveyance tubing system during each production cycle, the bore of the subsurface production tubing string remains clear of all earthen 19 particulate accumulations, rock fragments, pyrite balls and coal fragments as practically all hydrocarbon, earthen matter and water are purged through the 21 subsurface production tubing and surface flow line, at a sufficient fluid velocity to entrain and carry earthen matter within the hydrocarbon fluid to surface 23 storage. As the method does not employ a subsurface production pump, subsurface production pump wear and damage caused by pumping high fluid pressures due to blockages or considerable accumulations of earthen particulates, rock and coal fragments, pyrite balls, or high water cuts is 27 eliminated.
In practice, the method of the present invention provides a hydrocarbon production method and apparatus that can displace hydrocarbon fluid from difficult oil wells without the problems of mild or extreme friction or premature subsurface component wear, earthen accumulations, particulate blockages or equipment flexibility limitations within deviated well-bores. Within oil wells that tend to pump dry frequently or unexpectedly, the method and apparatus of the 7 present invention can operate impervious to equipment damage over any length of time without liquid inflow from the subterranean reservoir or other 9 fluid source.
11 In carrying out the present invention, hydrocarbon fluid is fed from an oil well's subterranean hydrocarbon reservoir, by means of hydrocarbon 13 reservoir pressure, through the casing perforations and into the lower well-bore. Hydrocarbon fluid from the well-bore is flooded into and through a 15 subsurface intake valve, and into the lower subsurface end of the compressed gas conveyance tubing system by means of vacuum created 17 within the subsurface section of the compressed gas conveyance tubing system, or forced into the lower end of the subsurface section of the 19 compressed gas conveyance tubing system by means of the hydrocarbon fluid head pressure within the well-bore, or by a combination of vacuum and 21 fluid head pressure, or by subterranean hydrocarbon reservoir pressure. The subsurface intake valve is then closed and the hydrocarbon fluid is trapped 23 and contained within the lower subsurface section of the compressed gas conveyance tubing system.
25 A desired gas, or any practical gas of convenience such as natural gas, air, carbon dioxide or steam may be compressed and fed through the oil well's 27 compressed gas conveyance tubing system, with sufficient volume and pressure as is required to purge the hydrocarbon fluid and it's earthen particulates up through the subsurface production tubing string, through the wellhead, through a surface flow line and into a hydrocarbon fluid storage 3 tank or other handling facility at surface. If desired, after the main volume of hydrocarbon fluid and it's contaminants are displaced to surface storage facilities, the compressed gas feed may be continued for a snort time to entrain and carry residual produced hydrocarbon, earthen material and water 7 from the compressed gas conveyance tubing system and surface flow line to the surface hydrocarbon production fluid storage tank or other handling 9 facilities at surface.
11 Any number of optional modes or accessories may be added to the production system to provide solutions for problems within individual oil wells 13 including automation to operate the compressed gas feed valve, the gas vent valves, and optional equipment. Automation may be used to direct the production system to run idle or shut down for a decided period of time, or an automated well-bore fluid level sensor may be employed to slow down, shut 17 down, or speed up the production system, enabling said production system to respond automatically to the hydrocarbon fluid level within the well-bore.
In some cases a vacuum assisted hydrocarbon fluid intake mode is 21 used to draw hydrocarbon fluid into the lower end of the subsurface compressed gas conveyance tubing system as illustrated in Figure 3. The 23 subsurface production tubing string or the subsurface compressed gas feed tubing string or both tubing strings may be evacuated of gas, by venting and/or by vacuum pump means, to intake hydrocarbon fluid into the subsurface tubing string(s), the choice being dependant upon equipment or 27 design preference, special conditions or system setup. A dedicated gas compressor and a dedicated vacuum pump may be used within the hydrocarbon production system installation, or a single gas compressor may serve as a gas compressor and as a vacuum pump in the same hydrocarbon production installation. Gas scrubbers and gas filters may be installed into the hydrocarbon production system as desired to protect gas compressors, vacuum pumps and other devices from in-taking earthen particulates, water droplets, hydrocarbon globules or vapours.
The greater amount of gas may be removed from the hydrocarbon fluid 9 as the hydrocarbon fluid is fed into the hydrocarbon production fluid storage tank. The gas separation conduit preferably should have an inside diameter 11 of sufficient size to conduct the hydrocarbon fluid, by gravity means, to a lower level of the hydrocarbon production fluid storage tank without having 13 excessive spillage of hydrocarbon fluid out the top of the gas separation conduit. In selecting the inside diameter of the gas separation conduit, 15 consideration should be given to the hydrocarbon fluid's expected input volume and viscosity.
The subsurface compressed gas feed tubing string and the subsurface 19 production tubing string may be suspended from or through the wellhead parallel to each other within the well-bore, or one of the subsurface tubing 21 strings may be more conveniently placed inside the other and one tubing string can exit the wellhead through a stuffing box or other suitable pack-off to 23 simplify installation.
25 The method of the present invention requires venting of gas from several of the hydrocarbon production system's components in order for the 27 hydrocarbon production system to function correctly, not explode, and displace hydrocarbon fluid to surface storage efficiently. Figures 2 and 4 illustrate gas venting, but Figure 3 has altered gas venting due to a different equipment setup. A person skilled in the art will appreciate the system's design flexibility and adaptability to direct venting of some or all gases from different outlet positions to various optional gas destinations for further use, or to other gas collecting facilities, or to a vapour recovery system, or to implement design changes to comply with government energy board 7 regulations, environmental, Boiler Branch, safety, or other issues.
9 When displacing viscose, earthen solids laden or other hydrocarbon fluid from a horizontal well-bore, the lower end of the compressed gas 11 conveyance tubing system may be constructed of an oil field grade of coiled tubing to more easily pass through the dog-legged section of the well-bore 13 and into the horizontal section of the well-bore, as illustrated in Figure 4.
The horizontal section of the subsurface compressed gas conveyance tubing 15 system may be equipped with numerous subsurface intake valves to more evenly flood hydrocarbon fluid from a greater span of the subsurface 17 hydrocarbon reservoir, into and through a greater span of casing perforations, sand screens or liner slots that feed hydrocarbon fluid from the subterranean 19 hydrocarbon reservoir into the horizontal well-bore. Due to the horizontal placement of the horizontal section of the subsurface compressed gas 21 conveyance tubing system, reed type intake valves having sufficiently sized ports that close by slight spring pressure or another desired valve may serve 23 as the subsurface intake valves. In some cases, one subsurface intake valve may be considered sufficient.
Within oil fields operating under a water-flood scheme, or wherein the 27 subterranean hydrocarbon reservoir contains and releases hydrocarbon fluid including large volumes of ground water, there is a need to rapidly displace such hydrocarbon fluid from the subterranean reservoir of an oil well to a hydrocarbon production fluid storage tank or other handling facilities at ground 3 surface. By sufficiently increasing the volume and pressure of compressed gas feed, or by reducing the inside diameter of the subsurface production tubing string, the hydrocarbon and water may be purged to surface storage facilities more efficiently, eliminating the problem of compressed gas bubbling 7 to surface through the mostly water column.
9 In some cases, a build-up of earthen particuiates, rack and coal fragments or pyrite balls may accumulate within the lower well-bore and 11 obstruct the flow of hydrocarbon fluid from entering the subsurface lower end of the compressed gas conveyance tubing system. By closing the well-bore's 13 casing gas vent valve, casing gas pressure will build and stop the flow of hydrocarbon fluid from the subterranean hydrocarbon reservoir into the well-bore. By purging all fluid from the compressed gas conveyance tubing system, and then feeding a sufficient volume and pressure of compressed gas 17 from surface, into and through the casing gas vent, through the well-bore, through the subsurface intake valve, and through the subsurface tubing string 19 and surface flow line and into the hydrocarbon fluid storage tank, earthen accumulations within the well-bore may be entrained and carried to surface 21 storage.
23 A wellhead output gas valve may be added to close off the compressed gas and hydrocarbon fluid flow between the wellhead output and the surface flow line's input end, in order to build sufficient compressed gas pressure within the subsurface compressed gas feed tubing string, and upon opening 27 the wellhead output gas valve, a hydrocarbon fluid column may be rapidly purged, at a considerable velocity, from and through the subsurface IS
production tubing string, through the wellhead, surface flow line, and into the hydrocarbon storage tank. The method is advantageous when there is 3 compressed gas loss due to bubble loss through the production tubing fluid column, or when difficult earthen particulates or rock fragments are to be entrained and carried to surface storage, or when improving heat transfer from compressed gas to hydrocarbon fluid, or when improving the fluid flow shear 7 effect. A rapid fluid column rise to surface and a very gentle "top of fluid column" entry into and through the wellhead, and a gentle "bottom of fluid 9 column" exciting out of the wellhead, may be achieved by calculating and providing the math governing the compression and decompression of gases, 11 subsurFace tubing volumes and lengths, fluid column weight and viscosity.
13 In cases where two or more oii wells are closely positioned, as on a pad with multiple oil wells, one gas compressor of sufficient capacity may be I 5 very efficiently used to supply the compressed gas for the multiple oil wells. A
programmable valve controller may be used to open and close many valves 17 as required to repetitively cycle each of the oil wells through their production cycles. As one or more oil wells are in the purge part of their production cycle, 19 one or more other oil wells may be in the fluid intake part of their production cycle or idle, and other oil wells may be waiting their turn.
1 BRIEF DESCRIPTION OI= THE DRAWINGS
3 Having thus generally described the invention, reference will now be made to the accompanying drawings illustrating preferred embodiments in which;
Figure 1 is a schematic illustration of a typical prior art system to 7 displace hydrocarbon fluid from a subterranean hydrocarbon reservoir to surface storage or handling facilities; and Figure 2 is a schematic illustration outlining the method of the present 11 invention to displace hydrocarbon fluid from a subterranean hydrocarbon reservoir to surface storage or handling facilities.
The schematic of Figure 2 additionally illustrates a method to displace a build-up of earthen particulates, rock or coal fragments or pyrite balls from within the lower well-bore to a hydrocarbon production fluid storage tank or 1'7 other handling facility at surface.
19 Figure 3 is a schematic illustration outlining the method of the present invention including the use of an optional vacuum assisted hydrocarbon fluid 21 intake.
23 Figure 4 is a schematic illustration outlining the method of the present invention displacing hydrocarbon fluid from a horizontal well-bore.
Figure 5 illustrates a method to separate gas from hydrocarbon fluid.
3 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 or lengths of conduit coupled 7 together from wellhead 6 to subsurface production pump 15. The system may also include what is commonly known as sucker rods 10. In use, hydrocarbon 9 fluid 13 is fed by means of subterranean hydrocarbon reservoir 16 pressure into well-bore 9 through casing perforations 14 and pumped from well-bore 9 11 by subsurface production pump 15, into and through production tubing 12, into and through wellhead 6, into and through surface flow line 21, into and 13 through optional surface check valve 20 and into hydrocarbon production fluid storage tank 22. Valve 7 is provided to vent casing gas. fJptional surface check valve 20 is provided to prevent stored hydrocarbon fluid 13 from back-flowing from hydrocarbon production fluid storage tank 22 into subsurface 17 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 21 conventional oil well production system is modified to displace hydrocarbon fluid from an oil well's subterranean hydrocarbon reservoir to a hydrocarbon 23 production fluid storage tank or other handling facility at surface by following the steps of;
providing a compressed gas conveyance tubing system extending from a source of compressed gas at ground surface, through the wellhead and 27 down the well-bore to the approximate subterranean hydrocarbon reservoir depth and returning up out of the well-bore, through the wellhead and into the 1g 1 hydrocarbon production fluid storage tank at surface, with said compressed gas conveyance tubing system including;
3 a source of compressed gas 1; valve 1a; conduit 2; conduit 3; valve 4; wellhead 6; casing gas vent 7; casing 8; well-bore 9; subsurface compressed gas feed tubing string 11; subsurface production tubing string 12; hydrocarbon fluid 13; casing perforations 7 14; subterranean hydrocarbon reservoir 16; subsurface intake valve 17; fluid communication port 18; conduit 19; optional surface check 9 valve 20; surface flow line 21; hydrocarbon production fluid storage tank 22; storage tank gas vent 23; optional gas separation conduit 11 24; gap 25;
flooding hydrocarbon fluid 13 from subterranean hydrocarbon reservoir I3 16 through casing perforations 14 into well-bore 9, by means of subterranean hydrocarbon reservoir 16 pressure; closing valve 1 a;
venting gas 1 from subsurface gas feed tubing string 11 through wellhead 6, into and through conduit 2, into and through conduit 3, into and through valve 17 4 to atmosphere or other gas handling facility; venting gas 1 from subsurface production tubing string 12, into and through conduit 19, into and through 19 optional surface check valve 20, into and through surface flow line 21 and into hydrocarbon production fluid storage tank 22; venting gas 1 from 21 hydrocarbon production fluid storage tank 22 through tank gas vent 23 to atmosphere or other gas handling facility;
23 flooding hydrocarbon fluid 13 from well-bore 9, by means of hydrocarbon fluid 13 head pressure, into and through subsurface intake valve 17 and into the lower ends of subsurface compressed gas feed tubing string 11 and subsurface production tubing string 12; containing hydrocarbon 27 fluid 13 within subsurface gas feed tubing string 11 and subsurface production tubing string 12 by means of closing subsurface intake valve 17 by gravity or 1 other means; closing valve 4; opening valve 1 a;
purging the flood of hydrocarbon fluid 13 contained within the lower 3 ends of subsurface compressed gas feed tubing string 11 and subsurface production tubing string 12, into hydrocarbon production fluid storage tank 22, by means of feeding a sufficient volume and pressure of compressed gas 1 from a source on surface, into and through valve 1a, into and through conduit 7 2, into and through wellhead 6, into and through subsurface gas feed tubing string 11, into and through fluid communication port 18, into and through 9 subsurface production tubing string 12, into and through conduit 19, into and through optional surface check valve 20, into and through flow line 21, and 11 into hydrocarbon production fluid storage tank 22; optionally separating the mixture of compressed gas 1 and hydrocarbon fluid 13 by feeding 13 hydrocarbon fluid 13 from the output end of conduit 21, through gap 25, into the open top end of and through optional gas separation conduit 24;
venting gas 1 from hydrocarbon production fluid storage tank 22 through storage tank gas vent 23 to atmosphere or other gas handling facility;
17 optionally preventing stored hydrocarbon fluid 13 and gas 1 from back-flowing from hydrocarbon production fluid storage tank 22 into subsurface production 19 tubing string 12 by means of optional surface check valve 20 ; repeating the hydrocarbon production system cycle for an indefinite period of time;
21 recovering hydrocarbon fluid 13 from hydrocarbon production fluid storage tank 22.
The schematic of Figure 2 additionally illustrates a means to displace a build-up of earthen particulates, rock and/or coal fragments and/or pyrite balls 1 from within the lower well-bore or approximate subsurface intake valve depth of the well-bore, to a hydrocarbon production fluid storage tank or other 3 handling facility at surface, comprising the steps of;
stopping the inflow of hydrocarbon fluid 13 into well-bore 9 from 5 subterranean hydrocarbon reservoir 16 by means of closing casing gas vent 7 and allowing time for the inflow of natural gas from subterranean hydrocarbon 7 reservoir 16 to pressurize well-bore 9; closing valve 4; opening valve 1 a; purging hydrocarbon fluid 13 from the lower ends of subsurface gas 9 feed tubing string 11 and subsurface production tubing string 12, into hydrocarbon production storage tank 22, by means of feeding a sufficient 11 volume and pressure of compressed gas 1 from a source on surface, into and through valve 1a, into and through conduit 2, into and through wellhead 6, 13 into and through subsurface gas feed tubing string 11, into and through fluid communication port 18, into and through subsurface production tubing string 15 12, into and through conduit 19, into and through optional surface check valve 20, into and through flow line 21, and into hydrocarbon production fluid 17 storage tank 22; closing valve 1 a; opening valve 4 and valve 20 to vent gas 1 from the subsurface end of the compressed gas conveyance tubing 19 system; allowing natural gas and hydrocarbon fluid 13 pressure within well-bore 9 to force and/or flood earthen particulates, rocks and hydrocarbon 21 fluid 13 into and through subsurface intake valve 17 and into the lower ends of subsurface gas feed tubing string 11 and subsurface production tubing string 23 12; repeating the fluid intake and purging steps as often as is necessary to clear the production tubing string of hydrocarbon fluid and earthen material; closing valve 1 a and closing valve 4; entraining and carrying 1 earthen material from well-bore 9 to storage tank 22 by means of feeding a sufficient volume and pressure of compressed gas 1 from a source on 3 surface, into and through casing gas vent 7, into and through well-bore 9, into and through subsurface intake valve 17, into and through fluid communication port 18, into and through subsurface production tubing string 12, into and through conduit 19, into and through optional surface check valve 20, into and 7 through surface flow line 21, and into hydrocarbon production fluid storage tank 22; continuing the feed of compressed gas 1 until a satisfactory 9 amount of earthen material is displaced from well-bore 9 to surface storage tank 22 or other handling facilities.
The schematic of Figure 3 illustrates the method of the present 13 invention to displace hydrocarbon fluid from an oil well's subterranean hydrocarbon reservoir to a hydrocarbon production fluid storage tank or other handling facilities at surface, while employing a vacuum assisted hydrocarbon fluid intake to assist the flooding of hydrocarbon fluid from the well-bore into 17 the lower ends of the subsurface gas feed tubing string and subsurface production tubing string, comprising the steps of;
19 providing a compressed gas conveyance tubing system extending from a source of compressed gas 1 at ground surface, through wellhead 6 and 21 down well-bore 9 to the approximate subterranean hydrocarbon reservoir 16 depth and returning up out of well-bore 9, through wellhead 6 and into 23 hydrocarbon production fluid storage tank 22 at surface, with said compressed gas conveyance tubing system including;
a source of compressed gas 1; valve 1a; conduit 2; conduit 3;
1 valve 4; valve 5; vacuum pump 5a; weilhead 6; casing gas vent 7; casing 8; well-bore 9; subsurface compressed gas feed tubing 3 string 11; subsurface production tubing string 12; hydrocarbon fluid 13; casing perforations 14; subterranean hydrocarbon reservoir 16;
subsurface intake valve 17; fluid communication port 18; conduit 19; surface check valve 20; surface flow line 21; hydrocarbon 7 production fluid storage tank 22; storage tank gas vent 23; optional gas separation conduit 24; gap 25;
9 flooding hydrocarbon fluid 13 from subterranean hydrocarbon reservoir 16 through casing perforations 14 into well-bore 9, by means of subterranean 11 hydrocarbon reservoir 16 pressure;
closing valve 1a; opening valve 4 and valve 5; closing valve 13 20; evacuating gas 1 from and creating a vacuum within subsurface compressed gas feed tubing string 11 and subsurface production tubing string 12 by means of vacuum pump 5a; venting gas from vacuum pump 5a; drawing and feeding hydrocarbon fluid 13 from well-bore 9 through 17 subsurface intake valve 17 by vacuum means and by hydrocarbon fluid 13 head pressure means, into the lower ends of subsurface gas feed tubing 19 string 11 and subsurface production tubing string 12; closing subsurface intake valve 17 by gravity or other means to contain hydrocarbon fluid 13 21 within the lower ends of subsurface gas feed tubing string 11 and subsurface production tubing string 12;
23 closing valve 4 and valve 5; opening valve 1 a; purging the flood of hydrocarbon fluid 13 contained within subsurface compressed gas feed tubing string 11 and subsurface production tubing string 12, into hydrocarbon 1 production fluid storage tank 22, by means of feeding compressed gas 1 from a source on surface into and through valve 1 a, into and through conduit 2, 3 into and through wellhead 16, into and through compressed gas feed tubing string 11, into and through fluid communication port 18, into and through production tubing string 12, into and through conduit 19, into and through surface check valve 20, into and through surface flow line 21 and into 7 hydrocarbon production fluid storage tank 22; optionally separating the mixture of compressed gas 1 and hydrocarbon fluid 13 by feeding 9 hydrocarbon fluid 13 from the output end of conduit 21, through gap 25, into the open top open end and through optional gas separation conduit 24;
11 preventing stored hydrocarbon fluid 13 and gas 1 from back-flowing from hydrocarbon production fluid storage tank 22 into subsurface production 13 tubing string 12, subsurface gas feed tubing string 11, or vacuum pump 5a, by means of surface check valve 20 ; venting compressed gas 1 from the upper level of hydrocarbon production fluid storage tank 22 and out of storage tank gas vent 23 to atmosphere or other gas 1 handling facility;
17 repeating the hydrocarbon production system cycle for an indefinite period of time; recovering hydrocarbon fluid 13 from hydrocarbon 19 production fluid storage tank 22.
21 According to the present invention, as illustrated in Figure 4, the conventional oil well production system is modified to displace hydrocarbon 23 fluid from the horizontal well-bore section of an oil well's subterranean hydrocarbon reservoir, to a hydrocarbon production fluid storage tank or other handling facility at ground surface by following the steps of;
1 providing a compressed gas conveyance tubing system extending from a source of compressed gas at surface, through the weNhead and down the 3 weft-bore, to the desired landing point within the horizontal section of the subterranean hydrocarbon reservoir and returning up out of the well-bore, through the wellhead and into the hydrocarbon production fluid storage tank or other handling facilities at surface, with said compressed gas conveyance 7 tubing system including;
a source of compressed gas 1; conduit 2; conduit 3; valve 4;
9 wellhead 6; casing gas vent 7; casing 8; well-bore 9; subsurface compressed gas feed tubing string 11; subsurface production tubing string 11 12; hydrocarbon fluid 13; casing perforations 14; subterranean hydrocarbon reservoir 16; one or more than one subsurface intake 13 valves) 17; fluid communication port 18; conduit 19; optional surface check valve 20; surface flow line 21; hydrocarbon production fluid storage tank 22; storage tank gas vent 23; optional gas separation conduit 24; gap 25;
17 flooding hydrocarbon fluid 13 from subterranean hydrocarbon reservoir 16 through casing perforations 14 into well-bore 9, by means of subterranean 19 hydrocarbon reservoir 16 pressure;
venting gas 1 from subsurface gas feed tubing string 11 through wellhead 6, 21 into and through conduit 2, into and through conduit 3, into and through valve 4 to atmosphere or other gas handling facility; venting gas 1 from subsurface 23 production tubing string 12, into and through conduit 19, into and through optional surface check valve 20, into and through surface flow line 21 and into hydrocarbon production fluid storage tank 22; venting gas 1 from 1 hydrocarbon production fluid storage tank 22 through tank gas vent 23 to atmosphere or other gas handling facility;
3 flooding hydrocarbon fluid 13 from well-bore 9, by means of well-bore hydrocarbon fluid 13 head pressure, into and through one or more than one 5 subsurface intake valves) 17 and into the lower ends of subsurface compressed gas feed tubing string 11 and subsurface production tubing string 7 12; containing hydrocarbon fluid 13 within subsurface compressed gas feed tubing string 11 and subsurface production tubing string 12 by means of 9 closing subsurface intake valve 17 by gravity, spring pressure or other means; closing valve 4;
11 purging the flood of hydrocarbon fluid 13 contained within the lower ends of subsurface compressed gas feed tubing string 11 and subsurface 13 production tubing string 12, into hydrocarbon production fluid storage tank 22, by means of feeding compressed gas 1 from a source on surface, into and 15 through conduit 2, into and through wellhead 6, into and through subsurface gas feed tubing string 11, into and through fluid communication port 18, into 17 and through subsurface production tubing string 12, into and through conduit 19, into and through optional surface check valve 20, into and through surface 19 flow line 21, and into hydrocarbon production fluid storage tank 22;
optionally separating the mixture of compressed gas 1 and 21 hydrocarbon fluid 13 by feeding hydrocarbon fluid 13 from the output end of conduit 21, through gap 25, into the top open end and through optional gas 23 separation conduit 24; venting gas 1 from hydrocarbon production fluid storage tank 22 through storage tank gas vent 23 to atmosphere or other gas 25 handling facility; optionally preventing stored hydrocarbon fluid 13 and gas 1 1 from back-flowing from hydrocarbon production fluid storage tank 22 into subsurface production tubing string 12 by means of optional surface check 3 valve 20 ; repeating the hydrocarbon production system cycle for an indefinite period of time; recovering hydrocarbon fluid 13 from S hydrocarbon production fluid storage tank 22.
7 According to the present invention, as illustrated in Figure 5, gas is optionally separated from hydrocarbon fluid by following the steps of;
9 providing optional gas separation conduit 24; placing optional gas separation conduit 24 vertically within hydrocarbon production fluid storage 11 tank 22; feeding hydrocarbon fluid from the output end of conduit 21, downward into the open upper end and through conduit 24, into the lower 13 level of hydrocarbon production fluid storage tank 22; permitting the flow of gas exiting conduit 21 to escape by means of open gap 25 between conduit 15 21 and conduit 24, into the upper level of the hydrocarbon production fluid storage tank 22; venting gas from the upper level of hydrocarbon 17 production fluid storage tank 22 into and through storage tank vent 23 to atmosphere or other gas collecting or handling facility; providing conduit 19 24 with an inside diameter of sufficient size to conduct the hydrocarbon fluid, by gravity means, to a lower level of the hydrocarbon production fluid storage 21 tank without having excessive spillage of hydrocarbon fluid out the top of conduit 24.
BACKGROUND OF THE INVENTION
The purpose of the method of the present invention is to provide an 7 improved method and an improved apparatus to displace light, medium, heavy or viscose hydrocarbon fluid from subterranean hydrocarbon reservoirs 9 to a hydrocarbon production fluid storage tank or other handling facilities on ground surface, by means of oil well production, including oil wells wherein ali I1 currently used hydrocarbon production systems are mechanically incapable of sustained or economic production.
The method of the present invention provides a means to intake L5 hydrocarbon fluid, including any accompanying ground water or earthen contaminants, into the subsurface lower end of a tubing system. Compressed 17 gas is then used to purge the hydrocarbon fluid from within the tubing system to a hydrocarbon production fluid storage tank or other handling facility at 19 surface. Other than hydrocarbon fluid and gas movement, the ball of a subsurface intake valve is the production system's only moving subsurface 21 component. A titanium subsurface intake valve is commonly available and has a much extended service life even when displacing hydrocarbons 23 containing very high volumes of earthen materials including pyrite balls, rock and coal fragments, ground water, fine or course water sand or oil sand. The 25 possibility of such earthen materials accumulating within or causing blockages within the subsurface production tubing or surface flow line is most improbable, as there is no way to prevent the increased velocity of hydrocarbon fluid from entraining and carrying such earthen solids through the 3 subsurface production tubing and surface flow line to surface storage during the oil welt production operation. The method is also useful in displacing hydrocarbon fluid from well-bores that deviate off the vertical due to drilling problems or intentional deviations caused in drilling slant, whipstocked or 7 horizontal oil wells.
Subterranean hydrocarbon reservoir characteristics, hydrocarbon fluid 11 characteristics, drilling problems or the well-bore design within some oil wells may present problems wherein continuous or more economical hydrocarbon 13 production is difficult or not possible while employing current production systems including subsurface sucker rod driven plunger pumps and progressive cavity pumps or other types of subsurface production pumps.
Sucker rod activated tubing liner or insert type subsurface production 17 pumps are the mainstay of most oil fields around the world, and are very well suited to the production of light and medium hydrocarbons and will often 19 operate trouble free for several years. When used for the production of more viscose hydrocarbons, heavy oil or bitumen, the sucker rods will often float on 21 the downstroke and must be slowed down to prevent pump jack and sucker rod damage. If the hydrocarbon fluid contains considerable amounts of 23 earthen particulates, the earthen particulates may accumulate and cause blockages within the subsurface production tubing and surface flow line.
When the accumulation of earthen particulates becomes too great, the sucker rods simply will not fall at an acceptable fall rate, through the column of 27 hydrocarbon and earthen materials, production thereby fails, and well servicing is required. The earthen particulates also cause extreme abrasion of 1 the sucker rods and production tubing and premature failure of each, which requires replacement of each. Sucker rod and production tubing abrasion, 3 wear and mechanical stress is greatly increased in oil wells that have deviations off the vertical line due to drilling problems, or in slant, whipstocked or horizontal well-bores.
7 Progressing cavity subsurface production pumps driven by sucker rods are more successful in the production of the more viscose hydrocarbons and 9 are, to a degree, somewhat better able to cope with earthen particulates.
These pumps inherit all the problems associated with sucker rod use, are 1 I quickly destroyed when the well-bore fluid is pumped off or the rotors and stators will be badly damaged when pumping rock fragments or pyrite balls or 13 sand slugs. They have a much shortened life when pumping high amounts of earthen particulates, especially water sand. Within many oilsands production wells, seizure of the sucker rods by accumulations of earthen particulates packed within the subsurface production tubing string is a never ending 17 problem that may occur daily. The rubber stator component of the progressing cavity subsurface production pump is easily damaged by sand 19 slugs, rock or coal fragments, pebbles, pyrite balls or the high pumping pressure encountered when accumulations of earthen particulates begin to 21 block the flow of hydrocarbon production within the subsurface production tubing or surface flow line.
A great number of oil wells producing heavy oil or bitumen from earthen particulate laden subterranean hydrocarbon reservoirs would be rendered technically or economically inoperable without the very expensive 27 and frequent backup services of auxiliary equipment including pressure trucks, flush-by rigs, well servicing rigs or coiled tubing rigs to remove accumulated earthen particle build-up andlor blockages from the oil well's well-bore, subsurface production pump, subsurface production tubing. and surface flow line. Frequent replacement of subsurface components due to excessive metal to metal wear andlor metal wear due to the presence of abrasive produced earthen particulates within slant, horizontal, vertical or deviated well-bores presents considerable replacement cost in addition to the economic loss of 7 sales revenue due to oil well down time.
9 Within a horizontal well-bore it would be advantageous to land a sucker rod activated subsurface production pump within or below the dog-leg.
11 This is not usually practical due to the sharp production tubing curve, or dog-leg, wherein the sucker rods must rotate or reciprocate, causing excessive 13 wear, fatigue and very rapid failure of sucker rods and/or subsurface production tubing. Horizontal oil wells having subsurface production pumps 15 placed within or above the well-bore's dog-leg often have a problem with earthen particulates precipitating from the hydrocarbon fluid being drawn to 17 the subsurface production pump and accumulating within the horizontal section of the well-bore and within the dog- legged section of the well-bore.
19 Such precipitated accumulations continue to increase in volume until the flow of hydrocarbon fluid from the subterranean hydrocarbon reservoir is blocked 21 from the intake of the subsurface production pump, and hydrocarbon production cannot be restarted until the earthen particulates are removed from 23 the well-bore.
25 Commonly, very considerable amounts of earthen particulates precipitate from the hydrocarbon fluid, after being drawn into the subsurface 27 production pump and accumulate within the subsurface production tubing string andlor surface flow line. Eventually, precipitated earthen particulate accumulations may cause production failure wherein production cannot be restarted until the earthen particulates are removed from the subsurface 3 production tubing. The problem of earthen particle precipitation within tubulars is greatly increased when water production of 18% or greater 5 accompanies the hydrocarbon fluid. New subsurface progressing cavity pump service life or operating time within such oil wells can often be as short as a 7 day or two. If such oil wells do not clean up after spending substantial amounts of time, money and fruitless effort, such oil wells are sooner or later 9 considered to be mechanically or economically not viable, and are usually sold or abandoned.
SUMMARY OF THE INVENTION
13 More particularly, in accordance with one aspect of this invention, there is provided a compressed gas conveyance tubing system extending from a source of compressed gas at surface, down into and returning up out of an oil well having a subterranean hydrocarbon reservoir, oil well casing and casing 17 perforations that provide hydrocarbon fluid inflow from the subsurface hydrocarbon reservoir into the well-bore, the improvement comprising a 19 compressed gas conveyance tubing system including;
a source of compressed gas; a wellhead; conduit means to 21 connect the source of compressed gas to the wellhead; a subsurface compressed gas feed tubing string extending from a connection at the 23 wellhead to the approximate subsurface hydrocarbon reservoir depth of the well-bore; a subsurface production tubing string extending from the approximate subsurface hydrocarbon reservoir depth, through the wellhead to a surface flow line connection; a surface flow line with a connection at one 27 end to the subsurface production tubing string, and a connection at the other end to a hydrocarbon production fluid storage tank; a hydrocarbon production fluid storage tank; means to vent gas from the hydrocarbon production fluid storage tank; a subsurface intake valve connected to the lower subsurface end of the compressed gas conveyance tubing system;
means for fluid communication through the subsurface intake valve into the subsurface production tubing string and the subsurface compressed gas feed tubing string; means for fluid and gas communication through the 7 subsurface compressed gas feed tubing string into the subsurface production tubing string; valve means to vent gas from the subsurface production 9 tubing string; valve means to vent gas from the subsurface compressed gas feed tubing string;
In another aspect of the present invention, there is provided an 13 improvement in a method of displacing various grades of hydrocarbon fluid from subterranean hydrocarbon reservoirs to surface storage by means of oil 15 well production, which method includes the steps of;
Flooding hydrocarbon fluid from the subterranean hydrocarbon 17 reservoir into the well-bore; evacuating or venting gas from within the subsurface section of the compressed gas conveyance tubing system;
19 flooding hydrocarbon fluid from the weN-bore through a subsurface intake valve and into the lower subsurface end of the compressed gas conveyance 21 tubing system; closing the subsurface intake valve to contain the hydrocarbon fluid within the lower subsurface end of the compressed gas 23 conveyance tubing system;
purging hydrocarbon fluid contained within the lower subsurface end of 25 the compressed gas conveyance tubing system into a hydrocarbon production fluid storage tank at surface by means of feeding compressed gas from a 27 source at surface, through the compressed gas conveyance tubing system and into the hydrocarbon production fluid storage tank or other handling facility on surface; repeating the cycle; providing a means to separate hydrocarbon fluid and gas; providing means to recover hydrocarbon fluid from the hydrocarbon production fluid storage tank or other handling facility at surface.
In the present system and method, in order to repetitively cycle the 7 hydrocarbon production system through the production cycle, employ optional operating modes, and apply the use of optional devices, it is recommended 9 that a preferably programabfe or other suitable gas valve controller is employed to activate the gas valves as required, to repetitively direct the 11 production system through it's operating modes and cycles.
13 The subsurface compressed gas feed tubing string and the subsurface production tubing string are vented of gas when necessary, by means of gas 15 venting valves at surface, allowing well-bore fluid head pressure and/or optional vacuum created within the subsurface compressed gas conveyance 17 tubing system by an optional vacuum pump at surface, to flood hydrocarbon fluid from the well-bore, into and through the subsurface intake valve and into 19 the lower subsurface end of the compressed gas conveyance tubing system.
The subsurface intake valve is then closed by gravity or other means, to trap 21 the hydrocarbon fluid therein.
The hydrocarbon fluid trapped within the subsurface compressed gas 23 feed tubing string and subsurface production tubing string is purged, or forced by means of gas displacement, up the subsurface production tubing string, 25 through the optional surface check valve, into and through the surface flow line, and into the hydrocarbon production fluid storage tank or other handling 27 facilities at surface. Optional modes and devices, as will be described later, may be incorporated into the present system.
As gas is compressed by the gas compressor in order to purge hydrocarbon fluid from the subsurface compressed gas conveyance tubing system to surface storage, much of the heat therein generated is carried by the compressed gas, into and through the subsurface compressed gas conveyance tubing system and may be used to heat the hydrocarbon fluid contained therein, by means of close contact, conduction or radiation between 7 the heated subsurface compressed gas tubing string and the subsurface production tubing string. The heat transfer process may be readily 9 understood by studying Figure 2, and is very useful in making viscose hydrocarbon fluid less viscose, and subsequently reduces the required 11 horsepower output of the gas compressor's prime mover and the gas compression required to purge the hydrocarbon fluid contained within the 13 subsurface compressed gas conveyance tubing system to surface storage.
The heat transfer method further serves to provide a small saving in the 15 amount of energy required to heat the hydrocarbon fluid within the surface hydrocarbon production fluid storage tank.
In the present system and method, use is made of the fact that a 19 compressed gas feed of sufficient volume and pressure can be employed to purge fluid volumes at considerable velocities through horizontal, vertical or 21 inclined conduits. The increased fluid velocity additionally provides increased viscose hydrocarbon fluid shear properties and decreased fluid flow friction 23 factors within the conduits. The fluid velocity, during a normal production cycle, also provides a hydrocarbon fluid carrier stream to entrain and carry 25 precipitated earthen particulate matter and rock fragments from the subterranean reservoir depth of the oil well, up the subsurface production 27 tubing string, through the surface flow line and into a hydrocarbon production fluid storage tank or other handling facilities at surface.
ft may be realized that the production apparatus of the present 3 invention does not have sucker rods, or any moving subsurface components other than the ball of a subsurface intake valve, therefore extreme or mild sucker rod tensite stress and wear and abrasion between the none-existing sucker rods and the production tubing string is eliminated. Because there are 7 no sucker rods, the method of the present invention is useful within oil wells that have any type of deviation from the vertical, such as well-bores that are 9 vertical, vertical with drilling deviations, slant, whipstocked or horizontal. The method encourages insertion of the subsurface lower end of the compressed 11 gas conveyance tubing system into and through the dog-legged section of a horizontal well-bore in order to achieve hydrocarbon fluid extraction directly 13 from the horizontal section of the well-bore. This advantage eliminates the precipitation and accumulation of earthen particulates that would otherwise accumulate and solidly plug the dog-legged section and entry section of the horizontal well-bore. By means of the compressed gas fed through the 17 compressed gas conveyance tubing system during each production cycle, the bore of the subsurface production tubing string remains clear of all earthen 19 particulate accumulations, rock fragments, pyrite balls and coal fragments as practically all hydrocarbon, earthen matter and water are purged through the 21 subsurface production tubing and surface flow line, at a sufficient fluid velocity to entrain and carry earthen matter within the hydrocarbon fluid to surface 23 storage. As the method does not employ a subsurface production pump, subsurface production pump wear and damage caused by pumping high fluid pressures due to blockages or considerable accumulations of earthen particulates, rock and coal fragments, pyrite balls, or high water cuts is 27 eliminated.
In practice, the method of the present invention provides a hydrocarbon production method and apparatus that can displace hydrocarbon fluid from difficult oil wells without the problems of mild or extreme friction or premature subsurface component wear, earthen accumulations, particulate blockages or equipment flexibility limitations within deviated well-bores. Within oil wells that tend to pump dry frequently or unexpectedly, the method and apparatus of the 7 present invention can operate impervious to equipment damage over any length of time without liquid inflow from the subterranean reservoir or other 9 fluid source.
11 In carrying out the present invention, hydrocarbon fluid is fed from an oil well's subterranean hydrocarbon reservoir, by means of hydrocarbon 13 reservoir pressure, through the casing perforations and into the lower well-bore. Hydrocarbon fluid from the well-bore is flooded into and through a 15 subsurface intake valve, and into the lower subsurface end of the compressed gas conveyance tubing system by means of vacuum created 17 within the subsurface section of the compressed gas conveyance tubing system, or forced into the lower end of the subsurface section of the 19 compressed gas conveyance tubing system by means of the hydrocarbon fluid head pressure within the well-bore, or by a combination of vacuum and 21 fluid head pressure, or by subterranean hydrocarbon reservoir pressure. The subsurface intake valve is then closed and the hydrocarbon fluid is trapped 23 and contained within the lower subsurface section of the compressed gas conveyance tubing system.
25 A desired gas, or any practical gas of convenience such as natural gas, air, carbon dioxide or steam may be compressed and fed through the oil well's 27 compressed gas conveyance tubing system, with sufficient volume and pressure as is required to purge the hydrocarbon fluid and it's earthen particulates up through the subsurface production tubing string, through the wellhead, through a surface flow line and into a hydrocarbon fluid storage 3 tank or other handling facility at surface. If desired, after the main volume of hydrocarbon fluid and it's contaminants are displaced to surface storage facilities, the compressed gas feed may be continued for a snort time to entrain and carry residual produced hydrocarbon, earthen material and water 7 from the compressed gas conveyance tubing system and surface flow line to the surface hydrocarbon production fluid storage tank or other handling 9 facilities at surface.
11 Any number of optional modes or accessories may be added to the production system to provide solutions for problems within individual oil wells 13 including automation to operate the compressed gas feed valve, the gas vent valves, and optional equipment. Automation may be used to direct the production system to run idle or shut down for a decided period of time, or an automated well-bore fluid level sensor may be employed to slow down, shut 17 down, or speed up the production system, enabling said production system to respond automatically to the hydrocarbon fluid level within the well-bore.
In some cases a vacuum assisted hydrocarbon fluid intake mode is 21 used to draw hydrocarbon fluid into the lower end of the subsurface compressed gas conveyance tubing system as illustrated in Figure 3. The 23 subsurface production tubing string or the subsurface compressed gas feed tubing string or both tubing strings may be evacuated of gas, by venting and/or by vacuum pump means, to intake hydrocarbon fluid into the subsurface tubing string(s), the choice being dependant upon equipment or 27 design preference, special conditions or system setup. A dedicated gas compressor and a dedicated vacuum pump may be used within the hydrocarbon production system installation, or a single gas compressor may serve as a gas compressor and as a vacuum pump in the same hydrocarbon production installation. Gas scrubbers and gas filters may be installed into the hydrocarbon production system as desired to protect gas compressors, vacuum pumps and other devices from in-taking earthen particulates, water droplets, hydrocarbon globules or vapours.
The greater amount of gas may be removed from the hydrocarbon fluid 9 as the hydrocarbon fluid is fed into the hydrocarbon production fluid storage tank. The gas separation conduit preferably should have an inside diameter 11 of sufficient size to conduct the hydrocarbon fluid, by gravity means, to a lower level of the hydrocarbon production fluid storage tank without having 13 excessive spillage of hydrocarbon fluid out the top of the gas separation conduit. In selecting the inside diameter of the gas separation conduit, 15 consideration should be given to the hydrocarbon fluid's expected input volume and viscosity.
The subsurface compressed gas feed tubing string and the subsurface 19 production tubing string may be suspended from or through the wellhead parallel to each other within the well-bore, or one of the subsurface tubing 21 strings may be more conveniently placed inside the other and one tubing string can exit the wellhead through a stuffing box or other suitable pack-off to 23 simplify installation.
25 The method of the present invention requires venting of gas from several of the hydrocarbon production system's components in order for the 27 hydrocarbon production system to function correctly, not explode, and displace hydrocarbon fluid to surface storage efficiently. Figures 2 and 4 illustrate gas venting, but Figure 3 has altered gas venting due to a different equipment setup. A person skilled in the art will appreciate the system's design flexibility and adaptability to direct venting of some or all gases from different outlet positions to various optional gas destinations for further use, or to other gas collecting facilities, or to a vapour recovery system, or to implement design changes to comply with government energy board 7 regulations, environmental, Boiler Branch, safety, or other issues.
9 When displacing viscose, earthen solids laden or other hydrocarbon fluid from a horizontal well-bore, the lower end of the compressed gas 11 conveyance tubing system may be constructed of an oil field grade of coiled tubing to more easily pass through the dog-legged section of the well-bore 13 and into the horizontal section of the well-bore, as illustrated in Figure 4.
The horizontal section of the subsurface compressed gas conveyance tubing 15 system may be equipped with numerous subsurface intake valves to more evenly flood hydrocarbon fluid from a greater span of the subsurface 17 hydrocarbon reservoir, into and through a greater span of casing perforations, sand screens or liner slots that feed hydrocarbon fluid from the subterranean 19 hydrocarbon reservoir into the horizontal well-bore. Due to the horizontal placement of the horizontal section of the subsurface compressed gas 21 conveyance tubing system, reed type intake valves having sufficiently sized ports that close by slight spring pressure or another desired valve may serve 23 as the subsurface intake valves. In some cases, one subsurface intake valve may be considered sufficient.
Within oil fields operating under a water-flood scheme, or wherein the 27 subterranean hydrocarbon reservoir contains and releases hydrocarbon fluid including large volumes of ground water, there is a need to rapidly displace such hydrocarbon fluid from the subterranean reservoir of an oil well to a hydrocarbon production fluid storage tank or other handling facilities at ground 3 surface. By sufficiently increasing the volume and pressure of compressed gas feed, or by reducing the inside diameter of the subsurface production tubing string, the hydrocarbon and water may be purged to surface storage facilities more efficiently, eliminating the problem of compressed gas bubbling 7 to surface through the mostly water column.
9 In some cases, a build-up of earthen particuiates, rack and coal fragments or pyrite balls may accumulate within the lower well-bore and 11 obstruct the flow of hydrocarbon fluid from entering the subsurface lower end of the compressed gas conveyance tubing system. By closing the well-bore's 13 casing gas vent valve, casing gas pressure will build and stop the flow of hydrocarbon fluid from the subterranean hydrocarbon reservoir into the well-bore. By purging all fluid from the compressed gas conveyance tubing system, and then feeding a sufficient volume and pressure of compressed gas 17 from surface, into and through the casing gas vent, through the well-bore, through the subsurface intake valve, and through the subsurface tubing string 19 and surface flow line and into the hydrocarbon fluid storage tank, earthen accumulations within the well-bore may be entrained and carried to surface 21 storage.
23 A wellhead output gas valve may be added to close off the compressed gas and hydrocarbon fluid flow between the wellhead output and the surface flow line's input end, in order to build sufficient compressed gas pressure within the subsurface compressed gas feed tubing string, and upon opening 27 the wellhead output gas valve, a hydrocarbon fluid column may be rapidly purged, at a considerable velocity, from and through the subsurface IS
production tubing string, through the wellhead, surface flow line, and into the hydrocarbon storage tank. The method is advantageous when there is 3 compressed gas loss due to bubble loss through the production tubing fluid column, or when difficult earthen particulates or rock fragments are to be entrained and carried to surface storage, or when improving heat transfer from compressed gas to hydrocarbon fluid, or when improving the fluid flow shear 7 effect. A rapid fluid column rise to surface and a very gentle "top of fluid column" entry into and through the wellhead, and a gentle "bottom of fluid 9 column" exciting out of the wellhead, may be achieved by calculating and providing the math governing the compression and decompression of gases, 11 subsurFace tubing volumes and lengths, fluid column weight and viscosity.
13 In cases where two or more oii wells are closely positioned, as on a pad with multiple oil wells, one gas compressor of sufficient capacity may be I 5 very efficiently used to supply the compressed gas for the multiple oil wells. A
programmable valve controller may be used to open and close many valves 17 as required to repetitively cycle each of the oil wells through their production cycles. As one or more oil wells are in the purge part of their production cycle, 19 one or more other oil wells may be in the fluid intake part of their production cycle or idle, and other oil wells may be waiting their turn.
1 BRIEF DESCRIPTION OI= THE DRAWINGS
3 Having thus generally described the invention, reference will now be made to the accompanying drawings illustrating preferred embodiments in which;
Figure 1 is a schematic illustration of a typical prior art system to 7 displace hydrocarbon fluid from a subterranean hydrocarbon reservoir to surface storage or handling facilities; and Figure 2 is a schematic illustration outlining the method of the present 11 invention to displace hydrocarbon fluid from a subterranean hydrocarbon reservoir to surface storage or handling facilities.
The schematic of Figure 2 additionally illustrates a method to displace a build-up of earthen particulates, rock or coal fragments or pyrite balls from within the lower well-bore to a hydrocarbon production fluid storage tank or 1'7 other handling facility at surface.
19 Figure 3 is a schematic illustration outlining the method of the present invention including the use of an optional vacuum assisted hydrocarbon fluid 21 intake.
23 Figure 4 is a schematic illustration outlining the method of the present invention displacing hydrocarbon fluid from a horizontal well-bore.
Figure 5 illustrates a method to separate gas from hydrocarbon fluid.
3 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 or lengths of conduit coupled 7 together from wellhead 6 to subsurface production pump 15. The system may also include what is commonly known as sucker rods 10. In use, hydrocarbon 9 fluid 13 is fed by means of subterranean hydrocarbon reservoir 16 pressure into well-bore 9 through casing perforations 14 and pumped from well-bore 9 11 by subsurface production pump 15, into and through production tubing 12, into and through wellhead 6, into and through surface flow line 21, into and 13 through optional surface check valve 20 and into hydrocarbon production fluid storage tank 22. Valve 7 is provided to vent casing gas. fJptional surface check valve 20 is provided to prevent stored hydrocarbon fluid 13 from back-flowing from hydrocarbon production fluid storage tank 22 into subsurface 17 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 21 conventional oil well production system is modified to displace hydrocarbon fluid from an oil well's subterranean hydrocarbon reservoir to a hydrocarbon 23 production fluid storage tank or other handling facility at surface by following the steps of;
providing a compressed gas conveyance tubing system extending from a source of compressed gas at ground surface, through the wellhead and 27 down the well-bore to the approximate subterranean hydrocarbon reservoir depth and returning up out of the well-bore, through the wellhead and into the 1g 1 hydrocarbon production fluid storage tank at surface, with said compressed gas conveyance tubing system including;
3 a source of compressed gas 1; valve 1a; conduit 2; conduit 3; valve 4; wellhead 6; casing gas vent 7; casing 8; well-bore 9; subsurface compressed gas feed tubing string 11; subsurface production tubing string 12; hydrocarbon fluid 13; casing perforations 7 14; subterranean hydrocarbon reservoir 16; subsurface intake valve 17; fluid communication port 18; conduit 19; optional surface check 9 valve 20; surface flow line 21; hydrocarbon production fluid storage tank 22; storage tank gas vent 23; optional gas separation conduit 11 24; gap 25;
flooding hydrocarbon fluid 13 from subterranean hydrocarbon reservoir I3 16 through casing perforations 14 into well-bore 9, by means of subterranean hydrocarbon reservoir 16 pressure; closing valve 1 a;
venting gas 1 from subsurface gas feed tubing string 11 through wellhead 6, into and through conduit 2, into and through conduit 3, into and through valve 17 4 to atmosphere or other gas handling facility; venting gas 1 from subsurface production tubing string 12, into and through conduit 19, into and through 19 optional surface check valve 20, into and through surface flow line 21 and into hydrocarbon production fluid storage tank 22; venting gas 1 from 21 hydrocarbon production fluid storage tank 22 through tank gas vent 23 to atmosphere or other gas handling facility;
23 flooding hydrocarbon fluid 13 from well-bore 9, by means of hydrocarbon fluid 13 head pressure, into and through subsurface intake valve 17 and into the lower ends of subsurface compressed gas feed tubing string 11 and subsurface production tubing string 12; containing hydrocarbon 27 fluid 13 within subsurface gas feed tubing string 11 and subsurface production tubing string 12 by means of closing subsurface intake valve 17 by gravity or 1 other means; closing valve 4; opening valve 1 a;
purging the flood of hydrocarbon fluid 13 contained within the lower 3 ends of subsurface compressed gas feed tubing string 11 and subsurface production tubing string 12, into hydrocarbon production fluid storage tank 22, by means of feeding a sufficient volume and pressure of compressed gas 1 from a source on surface, into and through valve 1a, into and through conduit 7 2, into and through wellhead 6, into and through subsurface gas feed tubing string 11, into and through fluid communication port 18, into and through 9 subsurface production tubing string 12, into and through conduit 19, into and through optional surface check valve 20, into and through flow line 21, and 11 into hydrocarbon production fluid storage tank 22; optionally separating the mixture of compressed gas 1 and hydrocarbon fluid 13 by feeding 13 hydrocarbon fluid 13 from the output end of conduit 21, through gap 25, into the open top end of and through optional gas separation conduit 24;
venting gas 1 from hydrocarbon production fluid storage tank 22 through storage tank gas vent 23 to atmosphere or other gas handling facility;
17 optionally preventing stored hydrocarbon fluid 13 and gas 1 from back-flowing from hydrocarbon production fluid storage tank 22 into subsurface production 19 tubing string 12 by means of optional surface check valve 20 ; repeating the hydrocarbon production system cycle for an indefinite period of time;
21 recovering hydrocarbon fluid 13 from hydrocarbon production fluid storage tank 22.
The schematic of Figure 2 additionally illustrates a means to displace a build-up of earthen particulates, rock and/or coal fragments and/or pyrite balls 1 from within the lower well-bore or approximate subsurface intake valve depth of the well-bore, to a hydrocarbon production fluid storage tank or other 3 handling facility at surface, comprising the steps of;
stopping the inflow of hydrocarbon fluid 13 into well-bore 9 from 5 subterranean hydrocarbon reservoir 16 by means of closing casing gas vent 7 and allowing time for the inflow of natural gas from subterranean hydrocarbon 7 reservoir 16 to pressurize well-bore 9; closing valve 4; opening valve 1 a; purging hydrocarbon fluid 13 from the lower ends of subsurface gas 9 feed tubing string 11 and subsurface production tubing string 12, into hydrocarbon production storage tank 22, by means of feeding a sufficient 11 volume and pressure of compressed gas 1 from a source on surface, into and through valve 1a, into and through conduit 2, into and through wellhead 6, 13 into and through subsurface gas feed tubing string 11, into and through fluid communication port 18, into and through subsurface production tubing string 15 12, into and through conduit 19, into and through optional surface check valve 20, into and through flow line 21, and into hydrocarbon production fluid 17 storage tank 22; closing valve 1 a; opening valve 4 and valve 20 to vent gas 1 from the subsurface end of the compressed gas conveyance tubing 19 system; allowing natural gas and hydrocarbon fluid 13 pressure within well-bore 9 to force and/or flood earthen particulates, rocks and hydrocarbon 21 fluid 13 into and through subsurface intake valve 17 and into the lower ends of subsurface gas feed tubing string 11 and subsurface production tubing string 23 12; repeating the fluid intake and purging steps as often as is necessary to clear the production tubing string of hydrocarbon fluid and earthen material; closing valve 1 a and closing valve 4; entraining and carrying 1 earthen material from well-bore 9 to storage tank 22 by means of feeding a sufficient volume and pressure of compressed gas 1 from a source on 3 surface, into and through casing gas vent 7, into and through well-bore 9, into and through subsurface intake valve 17, into and through fluid communication port 18, into and through subsurface production tubing string 12, into and through conduit 19, into and through optional surface check valve 20, into and 7 through surface flow line 21, and into hydrocarbon production fluid storage tank 22; continuing the feed of compressed gas 1 until a satisfactory 9 amount of earthen material is displaced from well-bore 9 to surface storage tank 22 or other handling facilities.
The schematic of Figure 3 illustrates the method of the present 13 invention to displace hydrocarbon fluid from an oil well's subterranean hydrocarbon reservoir to a hydrocarbon production fluid storage tank or other handling facilities at surface, while employing a vacuum assisted hydrocarbon fluid intake to assist the flooding of hydrocarbon fluid from the well-bore into 17 the lower ends of the subsurface gas feed tubing string and subsurface production tubing string, comprising the steps of;
19 providing a compressed gas conveyance tubing system extending from a source of compressed gas 1 at ground surface, through wellhead 6 and 21 down well-bore 9 to the approximate subterranean hydrocarbon reservoir 16 depth and returning up out of well-bore 9, through wellhead 6 and into 23 hydrocarbon production fluid storage tank 22 at surface, with said compressed gas conveyance tubing system including;
a source of compressed gas 1; valve 1a; conduit 2; conduit 3;
1 valve 4; valve 5; vacuum pump 5a; weilhead 6; casing gas vent 7; casing 8; well-bore 9; subsurface compressed gas feed tubing 3 string 11; subsurface production tubing string 12; hydrocarbon fluid 13; casing perforations 14; subterranean hydrocarbon reservoir 16;
subsurface intake valve 17; fluid communication port 18; conduit 19; surface check valve 20; surface flow line 21; hydrocarbon 7 production fluid storage tank 22; storage tank gas vent 23; optional gas separation conduit 24; gap 25;
9 flooding hydrocarbon fluid 13 from subterranean hydrocarbon reservoir 16 through casing perforations 14 into well-bore 9, by means of subterranean 11 hydrocarbon reservoir 16 pressure;
closing valve 1a; opening valve 4 and valve 5; closing valve 13 20; evacuating gas 1 from and creating a vacuum within subsurface compressed gas feed tubing string 11 and subsurface production tubing string 12 by means of vacuum pump 5a; venting gas from vacuum pump 5a; drawing and feeding hydrocarbon fluid 13 from well-bore 9 through 17 subsurface intake valve 17 by vacuum means and by hydrocarbon fluid 13 head pressure means, into the lower ends of subsurface gas feed tubing 19 string 11 and subsurface production tubing string 12; closing subsurface intake valve 17 by gravity or other means to contain hydrocarbon fluid 13 21 within the lower ends of subsurface gas feed tubing string 11 and subsurface production tubing string 12;
23 closing valve 4 and valve 5; opening valve 1 a; purging the flood of hydrocarbon fluid 13 contained within subsurface compressed gas feed tubing string 11 and subsurface production tubing string 12, into hydrocarbon 1 production fluid storage tank 22, by means of feeding compressed gas 1 from a source on surface into and through valve 1 a, into and through conduit 2, 3 into and through wellhead 16, into and through compressed gas feed tubing string 11, into and through fluid communication port 18, into and through production tubing string 12, into and through conduit 19, into and through surface check valve 20, into and through surface flow line 21 and into 7 hydrocarbon production fluid storage tank 22; optionally separating the mixture of compressed gas 1 and hydrocarbon fluid 13 by feeding 9 hydrocarbon fluid 13 from the output end of conduit 21, through gap 25, into the open top open end and through optional gas separation conduit 24;
11 preventing stored hydrocarbon fluid 13 and gas 1 from back-flowing from hydrocarbon production fluid storage tank 22 into subsurface production 13 tubing string 12, subsurface gas feed tubing string 11, or vacuum pump 5a, by means of surface check valve 20 ; venting compressed gas 1 from the upper level of hydrocarbon production fluid storage tank 22 and out of storage tank gas vent 23 to atmosphere or other gas 1 handling facility;
17 repeating the hydrocarbon production system cycle for an indefinite period of time; recovering hydrocarbon fluid 13 from hydrocarbon 19 production fluid storage tank 22.
21 According to the present invention, as illustrated in Figure 4, the conventional oil well production system is modified to displace hydrocarbon 23 fluid from the horizontal well-bore section of an oil well's subterranean hydrocarbon reservoir, to a hydrocarbon production fluid storage tank or other handling facility at ground surface by following the steps of;
1 providing a compressed gas conveyance tubing system extending from a source of compressed gas at surface, through the weNhead and down the 3 weft-bore, to the desired landing point within the horizontal section of the subterranean hydrocarbon reservoir and returning up out of the well-bore, through the wellhead and into the hydrocarbon production fluid storage tank or other handling facilities at surface, with said compressed gas conveyance 7 tubing system including;
a source of compressed gas 1; conduit 2; conduit 3; valve 4;
9 wellhead 6; casing gas vent 7; casing 8; well-bore 9; subsurface compressed gas feed tubing string 11; subsurface production tubing string 11 12; hydrocarbon fluid 13; casing perforations 14; subterranean hydrocarbon reservoir 16; one or more than one subsurface intake 13 valves) 17; fluid communication port 18; conduit 19; optional surface check valve 20; surface flow line 21; hydrocarbon production fluid storage tank 22; storage tank gas vent 23; optional gas separation conduit 24; gap 25;
17 flooding hydrocarbon fluid 13 from subterranean hydrocarbon reservoir 16 through casing perforations 14 into well-bore 9, by means of subterranean 19 hydrocarbon reservoir 16 pressure;
venting gas 1 from subsurface gas feed tubing string 11 through wellhead 6, 21 into and through conduit 2, into and through conduit 3, into and through valve 4 to atmosphere or other gas handling facility; venting gas 1 from subsurface 23 production tubing string 12, into and through conduit 19, into and through optional surface check valve 20, into and through surface flow line 21 and into hydrocarbon production fluid storage tank 22; venting gas 1 from 1 hydrocarbon production fluid storage tank 22 through tank gas vent 23 to atmosphere or other gas handling facility;
3 flooding hydrocarbon fluid 13 from well-bore 9, by means of well-bore hydrocarbon fluid 13 head pressure, into and through one or more than one 5 subsurface intake valves) 17 and into the lower ends of subsurface compressed gas feed tubing string 11 and subsurface production tubing string 7 12; containing hydrocarbon fluid 13 within subsurface compressed gas feed tubing string 11 and subsurface production tubing string 12 by means of 9 closing subsurface intake valve 17 by gravity, spring pressure or other means; closing valve 4;
11 purging the flood of hydrocarbon fluid 13 contained within the lower ends of subsurface compressed gas feed tubing string 11 and subsurface 13 production tubing string 12, into hydrocarbon production fluid storage tank 22, by means of feeding compressed gas 1 from a source on surface, into and 15 through conduit 2, into and through wellhead 6, into and through subsurface gas feed tubing string 11, into and through fluid communication port 18, into 17 and through subsurface production tubing string 12, into and through conduit 19, into and through optional surface check valve 20, into and through surface 19 flow line 21, and into hydrocarbon production fluid storage tank 22;
optionally separating the mixture of compressed gas 1 and 21 hydrocarbon fluid 13 by feeding hydrocarbon fluid 13 from the output end of conduit 21, through gap 25, into the top open end and through optional gas 23 separation conduit 24; venting gas 1 from hydrocarbon production fluid storage tank 22 through storage tank gas vent 23 to atmosphere or other gas 25 handling facility; optionally preventing stored hydrocarbon fluid 13 and gas 1 1 from back-flowing from hydrocarbon production fluid storage tank 22 into subsurface production tubing string 12 by means of optional surface check 3 valve 20 ; repeating the hydrocarbon production system cycle for an indefinite period of time; recovering hydrocarbon fluid 13 from S hydrocarbon production fluid storage tank 22.
7 According to the present invention, as illustrated in Figure 5, gas is optionally separated from hydrocarbon fluid by following the steps of;
9 providing optional gas separation conduit 24; placing optional gas separation conduit 24 vertically within hydrocarbon production fluid storage 11 tank 22; feeding hydrocarbon fluid from the output end of conduit 21, downward into the open upper end and through conduit 24, into the lower 13 level of hydrocarbon production fluid storage tank 22; permitting the flow of gas exiting conduit 21 to escape by means of open gap 25 between conduit 15 21 and conduit 24, into the upper level of the hydrocarbon production fluid storage tank 22; venting gas from the upper level of hydrocarbon 17 production fluid storage tank 22 into and through storage tank vent 23 to atmosphere or other gas collecting or handling facility; providing conduit 19 24 with an inside diameter of sufficient size to conduct the hydrocarbon fluid, by gravity means, to a lower level of the hydrocarbon production fluid storage 21 tank without having excessive spillage of hydrocarbon fluid out the top of conduit 24.
Claims (21)
1. A method of displacing hydrocarbon fluid which may contain 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, by means of a compressed gas conveyance tubing system, 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;
flooding hydrocarbon fluid from the subterranean hydrocarbon reservoir by means of subterranean hydrocarbon reservoir pressure, through the casing perforations and into the welt-bore;
venting gas from the subsurface section of the compressed gas conveyance tubing system;
flooding and containing hydrocarbon fluid from the well-bore by means of well-bore hydrocarbon fluid head pressure, into the lower subsurface end of the compressed gas conveyance tubing system;
purging the contained hydrocarbon fluid from within the subsurface section of the compressed gas conveyance tubing system, into the hydrocarbon production fluid storage tank at ground surface, by means of feeding a sufficient volume and pressure of compressed gas into and through the compressed gas conveyance tubing system, and into the hydrocarbon production fluid storage tank or other handling facilities at surface; separating gas and hydrocarbon fluid; venting gas from the hydrocarbon production fluid storage tank; repeating the hydrocarbon production system's production cycle; recovering hydrocarbon fluid 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;
flooding hydrocarbon fluid from the subterranean hydrocarbon reservoir by means of subterranean hydrocarbon reservoir pressure, through the casing perforations and into the welt-bore;
venting gas from the subsurface section of the compressed gas conveyance tubing system;
flooding and containing hydrocarbon fluid from the well-bore by means of well-bore hydrocarbon fluid head pressure, into the lower subsurface end of the compressed gas conveyance tubing system;
purging the contained hydrocarbon fluid from within the subsurface section of the compressed gas conveyance tubing system, into the hydrocarbon production fluid storage tank at ground surface, by means of feeding a sufficient volume and pressure of compressed gas into and through the compressed gas conveyance tubing system, and into the hydrocarbon production fluid storage tank or other handling facilities at surface; separating gas and hydrocarbon fluid; venting gas from the hydrocarbon production fluid storage tank; repeating the hydrocarbon production system's production cycle; recovering hydrocarbon fluid from the hydrocarbon production fluid storage tank or other facilities at ground surface;
2. A method of displacing hydrocarbon fluid which may contain earthen contaminants from the subterranean reservoir of an oil well to a hydrocarbon production fluid storage tank or other handling facilities at ground surface, by means of a compressed gas conveyance tubing system, and by means of a vacuum assisted hydrocarbon fluid intake, comprising the steps of;
evacuating gas from the subsurface section of the compressed gas conveyance tubing system by means of a vacuum pump of sufficient capacity; flooding hydrocarbon fluid from the well-bore, by vacuum means within the subsurface section of the compressed gas conveyance tubing system and by well-bore fluid head pressure means, into the lower subsurface end of the compressed gas conveyance tubing system, and containing the hydrocarbon fluid therein;
purging contained hydrocarbon fluid from within the subsurface section of the compressed gas conveyance tubing system, into the hydrocarbon production fluid storage tank at ground surface, by means of feeding a sufficient volume and pressure of compressed gas into and through the compressed gas conveyance tubing system, and into the hydrocarbon production fluid storage tank or other handling facilities at surface; separating gas and hydrocarbon fluid; venting gas from the hydrocarbon production fluid storage tank; repeating the hydrocarbon production system's production cycle; recovering hydrocarbon fluid from the hydrocarbon production fluid storage tank or other facilities at ground surface;
evacuating gas from the subsurface section of the compressed gas conveyance tubing system by means of a vacuum pump of sufficient capacity; flooding hydrocarbon fluid from the well-bore, by vacuum means within the subsurface section of the compressed gas conveyance tubing system and by well-bore fluid head pressure means, into the lower subsurface end of the compressed gas conveyance tubing system, and containing the hydrocarbon fluid therein;
purging contained hydrocarbon fluid from within the subsurface section of the compressed gas conveyance tubing system, into the hydrocarbon production fluid storage tank at ground surface, by means of feeding a sufficient volume and pressure of compressed gas into and through the compressed gas conveyance tubing system, and into the hydrocarbon production fluid storage tank or other handling facilities at surface; separating gas and hydrocarbon fluid; venting gas from the hydrocarbon production fluid storage tank; repeating the hydrocarbon production system's production cycle; recovering hydrocarbon fluid from the hydrocarbon production fluid storage tank or other facilities at ground surface;
3. A method of displacing hydrocarbon fluid which may contain earthen contaminants from an oil well's well-bore into the lower subsurface section of a compressed gas conveyance tubing system and containing the hydrocarbon fluid therein, comprising the steps of;
providing the method of Claim 1; venting gas pressure from within the lower subsurface section of the compressed gas conveyance tubing system; flooding hydrocarbon fluid from the well-bore by means of well-bore fluid head pressure, into and through the subsurface intake valve and into the compressed gas conveyance tubing system;
closing the subsurface intake valve to contain the hydrocarbon fluid within the compressed gas conveyance tubing system.
providing the method of Claim 1; venting gas pressure from within the lower subsurface section of the compressed gas conveyance tubing system; flooding hydrocarbon fluid from the well-bore by means of well-bore fluid head pressure, into and through the subsurface intake valve and into the compressed gas conveyance tubing system;
closing the subsurface intake valve to contain the hydrocarbon fluid within the compressed gas conveyance tubing system.
4. A vacuum assisted method of displacing hydrocarbon fluid which may contain earthen contaminants from an oil well's well-bore into the lower subsurface end of the compressed gas conveyance tubing system, and containing the hydrocarbon fluid therein, comprising the steps of;
providing the method of Claim 2; evacuating gas from within the subsurface section of the compressed gas conveyance tubing system by means of a vacuum pump; flooding hydrocarbon fluid from the well-bore by means of well-bore fluid head pressure, into and through the subsurface intake valve and into the lower subsurface section of the compressed gas conveyance tubing system; drawing hydrocarbon fluid from the well-bore, by means of vacuum, into and through the subsurface intake valve and into the lower subsurface end of the compressed gas conveyance tubing system; closing the subsurface intake valve to contain the hydrocarbon fluid within the subsurface section of the compressed gas conveyance tubing system.
providing the method of Claim 2; evacuating gas from within the subsurface section of the compressed gas conveyance tubing system by means of a vacuum pump; flooding hydrocarbon fluid from the well-bore by means of well-bore fluid head pressure, into and through the subsurface intake valve and into the lower subsurface section of the compressed gas conveyance tubing system; drawing hydrocarbon fluid from the well-bore, by means of vacuum, into and through the subsurface intake valve and into the lower subsurface end of the compressed gas conveyance tubing system; closing the subsurface intake valve to contain the hydrocarbon fluid within the subsurface section of the compressed gas conveyance tubing system.
5. A method of displacing hydrocarbon fluid which may contain earthen contaminants from the subsurface section of an oil well's compressed gas conveyance tubing system to a hydrocarbon production fluid storage tank or other handling facilities at ground surface, comprising the steps of;
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8;
purging hydrocarbon fluid and earthen contaminants from within the compressed gas conveyance tubing system into a hydrocarbon production fluid storage tank or other handling facilities at ground surface, by means of feeding a sufficient volume and pressure of compressed gas from a source at surface, through the compressed gas conveyance tubing system and into a storage tank or other handling facilities at surface.
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8;
purging hydrocarbon fluid and earthen contaminants from within the compressed gas conveyance tubing system into a hydrocarbon production fluid storage tank or other handling facilities at ground surface, by means of feeding a sufficient volume and pressure of compressed gas from a source at surface, through the compressed gas conveyance tubing system and into a storage tank or other handling facilities at surface.
6. A method of displacing hydrocarbon fluid which may contain earthen contaminants from the subterranean reservoir of an oil well to a hydrocarbon production fluid storage tank or other handling facilities at ground surface, without the use of a subsurface production pump, comprising the steps of;
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8.
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8.
7. A method of displacing hydrocarbon fluid which may contain earthen contaminants from a horizontal well-bore section placed within the subterranean hydrocarbon reservoir of an oil well, to a hydrocarbon production fluid storage tank or other handling facilities on ground surface, comprising the steps of;
providing the method of Claim 1 or Claim 2;
extending the compressed gas conveyance tubing system through the dog-legged section of the well-bore and into the horizontal section of the well-bore; providing the length of the subsurface horizontal section of the compressed gas conveyance tubing system with one or more subsurface intake valves fastened to an external surface of the compressed gas conveyance tubing system; venting or evacuating gas from the subsurface section of the compressed gas conveyance tubing system; flooding hydrocarbon fluid from the subterranean hydrocarbon reservoir, into horizontal section of the well-bore;
flooding hydrocarbon fluid from the horizontal section of the well-bore into and through the one or more subsurface intake valves and into the horizontal section of the subsurface compressed gas conveyance tubing system; containing the hydrocarbon fluid therein;
purging the hydrocarbon fluid from the subsurface section of the compressed gas conveyance tubing system to a hydrocarbon fluid storage tank or other handling facilities at surface.
providing the method of Claim 1 or Claim 2;
extending the compressed gas conveyance tubing system through the dog-legged section of the well-bore and into the horizontal section of the well-bore; providing the length of the subsurface horizontal section of the compressed gas conveyance tubing system with one or more subsurface intake valves fastened to an external surface of the compressed gas conveyance tubing system; venting or evacuating gas from the subsurface section of the compressed gas conveyance tubing system; flooding hydrocarbon fluid from the subterranean hydrocarbon reservoir, into horizontal section of the well-bore;
flooding hydrocarbon fluid from the horizontal section of the well-bore into and through the one or more subsurface intake valves and into the horizontal section of the subsurface compressed gas conveyance tubing system; containing the hydrocarbon fluid therein;
purging the hydrocarbon fluid from the subsurface section of the compressed gas conveyance tubing system to a hydrocarbon fluid storage tank or other handling facilities at surface.
8. A method to extract an even flow of hydrocarbon fluid from a long horizontal span of a subterranean hydrocarbon reservoir and displace the hydrocarbon fluid to a hydrocarbon fluid storage tank or other handling facilities at surface, comprising the steps of;
providing the method of Claim 1 or Claim 2; extending the compressed gas conveyance tubing system through the dog-legged section of the well-bore and into the horizontal section of the well-bore;
providing the length of the horizontal section of the subsurface compressed gas conveyance tubing system with two or more subsurface intake valves fastened to an external surface of the compressed gas conveyance tubing system; flooding an even flow of hydrocarbon fluid from over a long horizontal span of the subterranean hydrocarbon reservoir into and through the numerous casing perforations of a horizontally placed section of an oil well casing, liner or sand screen, and into the well-bore; venting or evacuating gas from the subsurface section of the compressed gas conveyance tubing system; flooding an even flow of hydrocarbon fluid from a long horizontal span of the well-bore, into and through two or more subsurface intake valves located along the long horizontal section of the compressed gas conveyance tubing system; containing the hydrocarbon fluid within the lower subsurface section of the compressed gas conveyance tubing system.
providing the method of Claim 1 or Claim 2; extending the compressed gas conveyance tubing system through the dog-legged section of the well-bore and into the horizontal section of the well-bore;
providing the length of the horizontal section of the subsurface compressed gas conveyance tubing system with two or more subsurface intake valves fastened to an external surface of the compressed gas conveyance tubing system; flooding an even flow of hydrocarbon fluid from over a long horizontal span of the subterranean hydrocarbon reservoir into and through the numerous casing perforations of a horizontally placed section of an oil well casing, liner or sand screen, and into the well-bore; venting or evacuating gas from the subsurface section of the compressed gas conveyance tubing system; flooding an even flow of hydrocarbon fluid from a long horizontal span of the well-bore, into and through two or more subsurface intake valves located along the long horizontal section of the compressed gas conveyance tubing system; containing the hydrocarbon fluid within the lower subsurface section of the compressed gas conveyance tubing system.
9. A method of displacing hydrocarbon fluid that contains water or earthen particulates or small rocks or sharp edged rock or coal fragments, or pyrite balls from the well-bore of an oil well to a hydrocarbon production fluid storage tank or other handling facilities at ground surface, by means of a compressed gas conveyance tubing system, comprising the steps of;
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8.
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8.
10. A method to eliminate sucker rod wear and subsurface production tubing wear caused by friction between the two, while displacing hydrocarbon fluid from a vertical or deviated well-bore to surface storage wherein the oil well has a continuing problem of excessive metal wear of the sucker rod string or the subsurface production tubing string during the normal pumping operation, comprising the steps of;
removing the conventional sucker rods and subsurface production pump; providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8.
removing the conventional sucker rods and subsurface production pump; providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8.
11. A method to displace hydrocarbon fluid which may contain earthen contaminants, to a storage tank or other handling facilities at surface, from an oil well that tends to run dry at indeterminable or unexpected times and remain dry for indeterminable periods of time, while the oil well pumping apparatus continues to operate steadily over productive periods and pumped off periods without damage to the oil well pumping apparatus during the pumped off periods, comprising the steps of;
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8.
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8.
12. A method to reduce the viscosity of hydrocarbon fluid within the subsurface of an oil well, comprising the steps of;
heating the hydrocarbon fluid within the subsurface hydrocarbon production tubing string by providing the method of Claim 14 or Claim 15 or Claim 16.
heating the hydrocarbon fluid within the subsurface hydrocarbon production tubing string by providing the method of Claim 14 or Claim 15 or Claim 16.
13. A method to reduce the energy required to displace hydrocarbon fluid from the lower end of the subsurface hydrocarbon production tubing string to surface storage or handling facilities, comprising the steps of;
reducing the hydrocarbon's fluid flow friction factor against the subsurface production tubing wall and surface flow line wall by providing the method of Claim 12; providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8.
reducing the hydrocarbon's fluid flow friction factor against the subsurface production tubing wall and surface flow line wall by providing the method of Claim 12; providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8.
14. A method to transfer heat from compressed gas into hydrocarbon fluid, wherein the subsurface hydrocarbon production tubing string is placed concentrically within the subsurface compressed gas feed tubing string, following the steps of;
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8, wherein the heated compressed gas fed through the subsurface compressed gas feed tubing string is in contact with the subsurface hydrocarbon production tubing string; permitting heat from the compressed gas to conduct through the wall of the subsurface hydrocarbon production tubing string and into the hydrocarbon fluid.
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8, wherein the heated compressed gas fed through the subsurface compressed gas feed tubing string is in contact with the subsurface hydrocarbon production tubing string; permitting heat from the compressed gas to conduct through the wall of the subsurface hydrocarbon production tubing string and into the hydrocarbon fluid.
15. A method to transfer heat from compressed gas into hydrocarbon fluid, wherein the subsurface compressed gas feed tubing string is placed concentrically within the subsurface hydrocarbon production tubing string, following the steps of;
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8;
permitting the heat from the compressed gas to conduct through the subsurface compressed gas feed tubing string wall and into the hydrocarbon fluid that is contained within or flowing through the subsurface hydrocarbon production tubing string.
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8;
permitting the heat from the compressed gas to conduct through the subsurface compressed gas feed tubing string wall and into the hydrocarbon fluid that is contained within or flowing through the subsurface hydrocarbon production tubing string.
16. A method to transfer heat from compressed gas into hydrocarbon fluid, wherein the subsurface compressed gas feed tubing string is placed parallel to the subsurface hydrocarbon production tubing string, following the steps of;
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8;
conducting compressed gas heat through the subsurface compressed gas feed tubing string's wall; radiating heat through the well-bore gas;
collecting and conducting the radiated heat into and through the hydrocarbon production tubing string's wail and into the hydrocarbon fluid.
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8;
conducting compressed gas heat through the subsurface compressed gas feed tubing string's wall; radiating heat through the well-bore gas;
collecting and conducting the radiated heat into and through the hydrocarbon production tubing string's wail and into the hydrocarbon fluid.
17. A method to displace accumulations of earthen particulates or rock or coal fragments or pyrite balls from an oil well's well-bore into a hydrocarbon production fluid storage tank or other handling and storage facility at surface, comprising the steps of;
providing the apparatus of Claim 1 or Claim 2 or Claim 7 or Claim 8;
stoping the inflow of hydrocarbon fluid from the subterranean hydrocarbon reservoir into the well-bore; purging hydrocarbon fluid from the lower subsurface end of the compressed gas conveyance tubing system, into the hydrocarbon production fluid storage tank or other handling facility at surface; venting gas or evacuating gas from the subsurface section of the compressed gas conveyance tubing system; allowing natural gas and hydrocarbon fluid head pressure within the well-bore to force or flood earthen particulates, rocks and hydrocarbon fluid into the lower subsurface end of the compressed gas conveyance tubing system;
repeating the purging and fluid intake steps as often as is necessary to clear the well-bore and production tubing string of hydrocarbon fluid and initial earthen matter; closing the compressed gas feed tubing string vent valve; closing the compressed gas conveyance tubing system's compressed gas feed valve; entraining and carrying earthen matter from the well-bore to the surface storage tank or other handling facilities at surface, by means of feeding a sufficient volume and pressure of compressed gas from a source on surface, into and through the casing gas vent, into and through the well-bore, into and through the subsurface intake valve, into and through the fluid communication port, into and through the subsurface production tubing string and surface flow line, and into the hydrocarbon production fluid storage tank; continuing the feed of compressed gas until a satisfactory amount of earthen matter is displaced from the well-bore to the surface storage tank or other handling facilities at surface.
providing the apparatus of Claim 1 or Claim 2 or Claim 7 or Claim 8;
stoping the inflow of hydrocarbon fluid from the subterranean hydrocarbon reservoir into the well-bore; purging hydrocarbon fluid from the lower subsurface end of the compressed gas conveyance tubing system, into the hydrocarbon production fluid storage tank or other handling facility at surface; venting gas or evacuating gas from the subsurface section of the compressed gas conveyance tubing system; allowing natural gas and hydrocarbon fluid head pressure within the well-bore to force or flood earthen particulates, rocks and hydrocarbon fluid into the lower subsurface end of the compressed gas conveyance tubing system;
repeating the purging and fluid intake steps as often as is necessary to clear the well-bore and production tubing string of hydrocarbon fluid and initial earthen matter; closing the compressed gas feed tubing string vent valve; closing the compressed gas conveyance tubing system's compressed gas feed valve; entraining and carrying earthen matter from the well-bore to the surface storage tank or other handling facilities at surface, by means of feeding a sufficient volume and pressure of compressed gas from a source on surface, into and through the casing gas vent, into and through the well-bore, into and through the subsurface intake valve, into and through the fluid communication port, into and through the subsurface production tubing string and surface flow line, and into the hydrocarbon production fluid storage tank; continuing the feed of compressed gas until a satisfactory amount of earthen matter is displaced from the well-bore to the surface storage tank or other handling facilities at surface.
18. A method to eliminate the 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 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 method of Claim 1 or Claim 2 or Claim 7 or Claim 8.
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8.
19. A method to eliminate subsurface production pump damage caused by pumping high hydrocarbon fluid pressures, or by pumping hydrocarbon fluid containing earthen particulates or small rocks or sharp edged rock fragments or pyrite balls, while displacing hydrocarbon fluid containing such earthen contaminants or fluid pressure 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;
removing the subsurface production pump and sucker rods; providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8.
removing the subsurface production pump and sucker rods; providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8.
20. A method of rapidly displacing hydrocarbon fluid including large volumes of ground water from the subterranean reservoir of an oil well to a hydrocarbon production fluid storage tank or other handling facilities at ground surface, by means of a compressed gas conveyance tubing system, comprising the steps of;
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8;
sufficiently increasing the volume and pressure of compressed gas to purge the hydrocarbon fluid from within the compressed gas conveyance tubing system to surface storageor other handling facilities.
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8;
sufficiently increasing the volume and pressure of compressed gas to purge the hydrocarbon fluid from within the compressed gas conveyance tubing system to surface storageor other handling facilities.
21. A method of rapidly displacing hydrocarbon fluid including large volumes of ground water from the subterranean reservoir of an oil well to a hydrocarbon production fluid storage tank or other handling facilities at ground surface, by means of a compressed gas conveyance tubing system, comprising the steps of;
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8;
sufficiently decreasing the inside diameter of the subsurface production tubing string.
providing the method of Claim 1 or Claim 2 or Claim 7 or Claim 8;
sufficiently decreasing the inside diameter of the subsurface production tubing string.
Priority Applications (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002511119A CA2511119A1 (en) | 2005-07-08 | 2005-07-08 | Hydrocarbon production system and method of use |
| US11/483,360 US20070012450A1 (en) | 2005-06-30 | 2006-07-10 | Hydrocarbon production system and method of use |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002511119A CA2511119A1 (en) | 2005-07-08 | 2005-07-08 | Hydrocarbon production system and method of use |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2511119A1 true CA2511119A1 (en) | 2007-01-08 |
Family
ID=37625878
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002511119A Abandoned CA2511119A1 (en) | 2005-06-30 | 2005-07-08 | Hydrocarbon production system and method of use |
Country Status (2)
| Country | Link |
|---|---|
| US (1) | US20070012450A1 (en) |
| CA (1) | CA2511119A1 (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110863795A (en) * | 2019-10-30 | 2020-03-06 | 中国石油天然气股份有限公司 | Method for removing accumulated liquid of ground pipeline through high-pressure air source |
Families Citing this family (11)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2006135744A2 (en) * | 2005-06-10 | 2006-12-21 | Rockwell Petroleum, Inc. | Oil extraction system and method |
| US7568527B2 (en) * | 2007-01-04 | 2009-08-04 | Rock Well Petroleum, Inc. | Method of collecting crude oil and crude oil collection header apparatus |
| US7543649B2 (en) * | 2007-01-11 | 2009-06-09 | Rock Well Petroleum Inc. | Method of collecting crude oil and crude oil collection header apparatus |
| US20080179063A1 (en) * | 2007-01-25 | 2008-07-31 | Smith David R | Chemically enhanced gas-lift for oil and gas wells |
| US7823662B2 (en) | 2007-06-20 | 2010-11-02 | New Era Petroleum, Llc. | Hydrocarbon recovery drill string apparatus, subterranean hydrocarbon recovery drilling methods, and subterranean hydrocarbon recovery methods |
| US20090008101A1 (en) * | 2007-07-06 | 2009-01-08 | Coady Patrick T | Method of Producing a Low Pressure Well |
| US7832483B2 (en) * | 2008-01-23 | 2010-11-16 | New Era Petroleum, Llc. | Methods of recovering hydrocarbons from oil shale and sub-surface oil shale recovery arrangements for recovering hydrocarbons from oil shale |
| CA2741581C (en) * | 2011-05-26 | 2015-02-17 | Newco Tank Corp. | Method and apparatus for heating a sales tank |
| WO2013024147A1 (en) * | 2011-08-18 | 2013-02-21 | Shell Internationale Research Maatschappij B.V. | System and method for producing a hydrocarbon product stream from a hydrocarbon well stream, and a hydrocarbon well stream separation tank |
| US20150013993A1 (en) * | 2013-07-15 | 2015-01-15 | Chevron U.S.A. Inc. | Downhole construction of vacuum insulated tubing |
| EP3308259A4 (en) * | 2015-06-12 | 2019-01-23 | Nureva Inc. | Method and apparatus for using gestures across multiple devices |
Family Cites Families (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3215087A (en) * | 1963-10-03 | 1965-11-02 | Exxon Production Research Co | Gas lift system |
| US3548939A (en) * | 1968-12-19 | 1970-12-22 | Sun Oil Co | Oil well production system |
| US5172717A (en) * | 1989-12-27 | 1992-12-22 | Otis Engineering Corporation | Well control system |
| US5971069A (en) * | 1997-08-08 | 1999-10-26 | Texaco Inc. | Well completion and production techniques |
| US6209641B1 (en) * | 1999-10-29 | 2001-04-03 | Atlantic Richfield Company | Method and apparatus for producing fluids while injecting gas through the same wellbore |
| MY128294A (en) * | 2000-03-02 | 2007-01-31 | Shell Int Research | Use of downhole high pressure gas in a gas-lift well |
| US6644400B2 (en) * | 2001-10-11 | 2003-11-11 | Abi Technology, Inc. | Backwash oil and gas production |
-
2005
- 2005-07-08 CA CA002511119A patent/CA2511119A1/en not_active Abandoned
-
2006
- 2006-07-10 US US11/483,360 patent/US20070012450A1/en not_active Abandoned
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110863795A (en) * | 2019-10-30 | 2020-03-06 | 中国石油天然气股份有限公司 | Method for removing accumulated liquid of ground pipeline through high-pressure air source |
Also Published As
| Publication number | Publication date |
|---|---|
| US20070012450A1 (en) | 2007-01-18 |
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| Date | Code | Title | Description |
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| EEER | Examination request | ||
| FZDE | Discontinued |