CA2247838C - Downhole oil/water separation system with solids separation - Google Patents
Downhole oil/water separation system with solids separation Download PDFInfo
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- CA2247838C CA2247838C CA002247838A CA2247838A CA2247838C CA 2247838 C CA2247838 C CA 2247838C CA 002247838 A CA002247838 A CA 002247838A CA 2247838 A CA2247838 A CA 2247838A CA 2247838 C CA2247838 C CA 2247838C
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- 239000007787 solid Substances 0.000 title claims abstract description 131
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 62
- 238000000926 separation method Methods 0.000 title abstract description 49
- 239000007788 liquid Substances 0.000 claims abstract description 79
- 238000004519 manufacturing process Methods 0.000 claims abstract description 49
- 239000012530 fluid Substances 0.000 claims abstract description 44
- 238000000034 method Methods 0.000 claims abstract description 21
- 239000003921 oil Substances 0.000 claims description 58
- 239000000203 mixture Substances 0.000 claims description 7
- 230000002250 progressing effect Effects 0.000 claims description 7
- 239000003129 oil well Substances 0.000 claims description 6
- 230000015572 biosynthetic process Effects 0.000 claims description 3
- 239000000411 inducer Substances 0.000 claims description 2
- 230000003068 static effect Effects 0.000 claims description 2
- 230000006735 deficit Effects 0.000 abstract description 2
- 239000012141 concentrate Substances 0.000 description 32
- 238000002347 injection Methods 0.000 description 23
- 239000007924 injection Substances 0.000 description 23
- 239000004576 sand Substances 0.000 description 10
- JTJMJGYZQZDUJJ-UHFFFAOYSA-N phencyclidine Chemical class C1CCCCN1C1(C=2C=CC=CC=2)CCCCC1 JTJMJGYZQZDUJJ-UHFFFAOYSA-N 0.000 description 6
- 239000000839 emulsion Substances 0.000 description 4
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- 230000007423 decrease Effects 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- RTAQQCXQSZGOHL-UHFFFAOYSA-N Titanium Chemical compound [Ti] RTAQQCXQSZGOHL-UHFFFAOYSA-N 0.000 description 1
- 238000005299 abrasion Methods 0.000 description 1
- 239000008186 active pharmaceutical agent Substances 0.000 description 1
- 239000000919 ceramic Substances 0.000 description 1
- 230000003628 erosive effect Effects 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 238000002955 isolation Methods 0.000 description 1
- 229910052751 metal Inorganic materials 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
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- 238000009428 plumbing Methods 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 238000009877 rendering Methods 0.000 description 1
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- 238000010008 shearing Methods 0.000 description 1
- 239000010936 titanium Substances 0.000 description 1
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/38—Arrangements for separating materials produced by the well in the well
- E21B43/385—Arrangements for separating materials produced by the well in the well by reinjecting the separated materials into an earth formation in the same well
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/35—Arrangements for separating materials produced by the well specially adapted for separating solids
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Cyclones (AREA)
Abstract
A downhole oil/water separation apparatus and process which separates solids from total production fluid prior to oil/water separation is disclosed. Production fluid is passed to a downhole solid/liquid cyclone which separates the fluid into a solids enriched stream and an oil/water stream. The oil is then commingled with the solids enriched stream and brought to surface. The water is reinjected downhole. The method effectively removes solids from the disposal fluid and thus avoids injectivity impairment caused by solids plugging.
Description
Downhole Oil/Water Separation System with Solids Separation This invention relates to a downhole oil/water separation process which separates solids to remove them from the disposal water stream.
Background of the Invention Many oil wells experience high water production. High water production is undesirable because it necessitates artificial lift systems which must accommodate the volume of water produced as well as water handling facilities at surface. These requirements add significantly to the operational and capital expenditures associated with production. In some circumstances, the production of wells and fields have been suspended or abandoned with significant volumes of oil left in the ground as a result of the poor economics resulting from excessive water production.
Downhole oil/water separation ("DHOWS") systems have been developed to contend with increased water production. Such systems incorporate the use of downhole liquid/liquid cyclones to separate the oil from the water. The separated oil is lifted to surface and the water is reinjected downhole. Unfortunately, the application of DHOWS systems in these wells is complicated by the inherent production of solids, such as sand, with the oil. The solids that are produced tend to remain in the disposal water stream which is reinjected downhole. Depending on the solids volume and well conditions, the solids may invade and plug the disposal zone or they may accumulate in the well bore.
In either case, the situation ultimately leads to a reduction in injectivity which reduces the effectiveness or precludes the further use of a DHOWS system.
Attempts have been made to remove sand from the disposal water stream. One such method is disclosed in International PCT ApplicationNo. GB96/02282 published as WO
97/12254 on March 17, 1997. According to that method, a liquid/liquid cyclone may be used to separate the production fluid into an oil enriched stream and a water enriched stream. The oil enriched stream is transported to the surface and the water enriched stream proceeds to a solid/liquid cyclone where the water is separated from the sand and then transported to a downhole disposal site.
While this method does provide a means for removing solids from production water before reinjecting it downhole, the presence of solids in the liquid/liquid cyclone causes significant erosion of that apparatus and the geometry and plumbing of the system have been found unfavourable. In addition, a system which removes solids downstream of the liquid/liquid cyclone cannot be easily incorporated into existing commercially available DHOWS systems.
Summary of the Invention The present invention provides a method for removing solids from total production fluid prior to separating the oil from the water by means of a downhole oil/water separation system. Production fluid is passed to a downhole solid/liquid cyclone which separates the fluid into a solids enriched stream and an oil/water stream. The oil/water stream then enters a liquid/liquid cyclone which separates the oil from the water. The oil is then commingled with the solids enriched stream and brought to surface. The water is reinjected downhole. The method effectively removes solids from the disposal fluid and thus avoids injectivity impairment caused by solids plugging.
Thus in accordance with the present invention there is provided a method for separating oil well production fluid containing oil, water and solids comprising:
transporting the production fluid to a downhole liquid/solid cyclone; separating the production fluid in the liquid/solid cyclone into a solids enriched stream at the cyclone underflow and a oil and water enriched stream at the cyclone overflow; transporting the oil and water enriched stream to a liquid/liquid cyclone; separating the oil and water enriched stream in the liquid/liquid cyclone into an oil enriched stream at the cyclone overflow and a water enriched stream at the cyclone underflow; transporting the water enriched stream to a downhole disposal site; and transporting the oil enriched stream and the solids enriched stream to surface.
In accordance with another aspect of the present invention, there is provided an apparatus for separating oil well production fluid containing oil, water and solids downhole comprising: at least one liquid/solid cyclone adapted to receive the production fluid and separate it into a solid enriched stream at an underflow outlet of said cyclone and an oil and water enriched stream at the overflow outlet of said cyclone; at least one liquid/liquid cyclone adapted to receive the oil and water enriched stream from the overflow of the liquid/solid cyclone and separate said stream into an oil enriched stream at an overflow outlet of said cyclone and a water enriched stream at an underflow outlet of said outlet;
a mixing means to mix the oil enriched stream with the solids enriched stream and produce an oil/solids stream; a first duct means to transport the oil enriched stream from the underflow outlet of the liquid/liquid cyclone to the mixing means; a second duct means to transport the solid enriched stream to the mixing means; and a third duct means to transport the oil/solids stream to surface.
Brief Description of the Drawings Figure 1 is a longitudinal cross sectional view of the apparatus of the present invention;
Figure 2 is a longitudinal cross sectional view of the solids separation unit of the present invention;
Figure 3 is a schematic representation illustrating the process of the present invention; and Figure 4a and 4b is a graphical representation of downhole production and injection results for the DHOWS with solids separation system of the present invention; and Figure 5 is a graphical representation of downhole production and injection results for the DHOWS
without solids separation system.
Figure 6 is a longitudinal cross sectional view of the solids separation unit of the present invention with a progressing cavity pump in a push through flow configuration;
Figure 7 is a longitudinal cross sectional view of the solids separation unit of the present invention with an electric submersible pump with a single shaft pump section in a push-through flow configuration;
Figure 8 is a longitudinal cross sectional view of the solids separation unit of the present invention with an electric submersible pump with a twin shaft pump section in a push-through flow configuration;
Background of the Invention Many oil wells experience high water production. High water production is undesirable because it necessitates artificial lift systems which must accommodate the volume of water produced as well as water handling facilities at surface. These requirements add significantly to the operational and capital expenditures associated with production. In some circumstances, the production of wells and fields have been suspended or abandoned with significant volumes of oil left in the ground as a result of the poor economics resulting from excessive water production.
Downhole oil/water separation ("DHOWS") systems have been developed to contend with increased water production. Such systems incorporate the use of downhole liquid/liquid cyclones to separate the oil from the water. The separated oil is lifted to surface and the water is reinjected downhole. Unfortunately, the application of DHOWS systems in these wells is complicated by the inherent production of solids, such as sand, with the oil. The solids that are produced tend to remain in the disposal water stream which is reinjected downhole. Depending on the solids volume and well conditions, the solids may invade and plug the disposal zone or they may accumulate in the well bore.
In either case, the situation ultimately leads to a reduction in injectivity which reduces the effectiveness or precludes the further use of a DHOWS system.
Attempts have been made to remove sand from the disposal water stream. One such method is disclosed in International PCT ApplicationNo. GB96/02282 published as WO
97/12254 on March 17, 1997. According to that method, a liquid/liquid cyclone may be used to separate the production fluid into an oil enriched stream and a water enriched stream. The oil enriched stream is transported to the surface and the water enriched stream proceeds to a solid/liquid cyclone where the water is separated from the sand and then transported to a downhole disposal site.
While this method does provide a means for removing solids from production water before reinjecting it downhole, the presence of solids in the liquid/liquid cyclone causes significant erosion of that apparatus and the geometry and plumbing of the system have been found unfavourable. In addition, a system which removes solids downstream of the liquid/liquid cyclone cannot be easily incorporated into existing commercially available DHOWS systems.
Summary of the Invention The present invention provides a method for removing solids from total production fluid prior to separating the oil from the water by means of a downhole oil/water separation system. Production fluid is passed to a downhole solid/liquid cyclone which separates the fluid into a solids enriched stream and an oil/water stream. The oil/water stream then enters a liquid/liquid cyclone which separates the oil from the water. The oil is then commingled with the solids enriched stream and brought to surface. The water is reinjected downhole. The method effectively removes solids from the disposal fluid and thus avoids injectivity impairment caused by solids plugging.
Thus in accordance with the present invention there is provided a method for separating oil well production fluid containing oil, water and solids comprising:
transporting the production fluid to a downhole liquid/solid cyclone; separating the production fluid in the liquid/solid cyclone into a solids enriched stream at the cyclone underflow and a oil and water enriched stream at the cyclone overflow; transporting the oil and water enriched stream to a liquid/liquid cyclone; separating the oil and water enriched stream in the liquid/liquid cyclone into an oil enriched stream at the cyclone overflow and a water enriched stream at the cyclone underflow; transporting the water enriched stream to a downhole disposal site; and transporting the oil enriched stream and the solids enriched stream to surface.
In accordance with another aspect of the present invention, there is provided an apparatus for separating oil well production fluid containing oil, water and solids downhole comprising: at least one liquid/solid cyclone adapted to receive the production fluid and separate it into a solid enriched stream at an underflow outlet of said cyclone and an oil and water enriched stream at the overflow outlet of said cyclone; at least one liquid/liquid cyclone adapted to receive the oil and water enriched stream from the overflow of the liquid/solid cyclone and separate said stream into an oil enriched stream at an overflow outlet of said cyclone and a water enriched stream at an underflow outlet of said outlet;
a mixing means to mix the oil enriched stream with the solids enriched stream and produce an oil/solids stream; a first duct means to transport the oil enriched stream from the underflow outlet of the liquid/liquid cyclone to the mixing means; a second duct means to transport the solid enriched stream to the mixing means; and a third duct means to transport the oil/solids stream to surface.
Brief Description of the Drawings Figure 1 is a longitudinal cross sectional view of the apparatus of the present invention;
Figure 2 is a longitudinal cross sectional view of the solids separation unit of the present invention;
Figure 3 is a schematic representation illustrating the process of the present invention; and Figure 4a and 4b is a graphical representation of downhole production and injection results for the DHOWS with solids separation system of the present invention; and Figure 5 is a graphical representation of downhole production and injection results for the DHOWS
without solids separation system.
Figure 6 is a longitudinal cross sectional view of the solids separation unit of the present invention with a progressing cavity pump in a push through flow configuration;
Figure 7 is a longitudinal cross sectional view of the solids separation unit of the present invention with an electric submersible pump with a single shaft pump section in a push-through flow configuration;
Figure 8 is a longitudinal cross sectional view of the solids separation unit of the present invention with an electric submersible pump with a twin shaft pump section in a push-through flow configuration;
Figure 9 is a longitudinal cross sectional view of the solids separation unit of the present invention with a high volume electric submersible pump with a twin shaft pump section in a pull-through flow configuration;
Figure 10 is a longitudinal cross sectional view of the solids separation unit of the present invention with an electric submersible pump with a twin motor pump section in a pull-through flow configuration;
Figure 11 is a schematic diagram showing an alternative arrangement using an orifice gallery and mixer for mixing the solids concentrate and oil concentrate streams.
Figures 12 is a schematic diagram showing an alternative arrangement using a jet pump for mixing the solids concentrate and oil concentrate streams.
Figures 13 is a schematic diagram showing an alternative arrangement using a progressing cavity pump for mixing the solids concentrate and oil concentrate streams.
Detailed Description of a Preferred Embodiment of the Invention With reference to Figure 1, well bore casing 2 penetrates the production formation and is provided with production perforations 4 in the area of the production zone to allow for intake of production fluid. Injection perforations 6 in well casing 2 are provided in the area of the injection zone to allow for egress of injection fluid. The injection zone may be above or below the production zone, depending on the well. Lower packer 8 isolates the production zone from the injection zone below. An upper packer (not shown) may be used if the characteristics of the particular well require it.
The well is equipped with artificial lift system 10 of progressing cavity pumps in the upper portion of well casing 2, liquid separation unit 12 in the lower portion of well casing 2, and solids separation unit 14 located between the pumps 10 and liquid separation system 12 and connected to each. Artificial lift system 10 consists of total production fluid pump 16 which is sized to pressurize the injection fluid for injection into the injection zone. Inlet screen 18 is adapted to receive total production fluid into pump 16. Total production feed line 17 extends from pump 16 to solids separation unit 14. Oil concentrate pump 20 is positioned above total production fluid pump 16 and has a capacity of preferably at least 20 m3/d/100rpm. Seal pump 22 provides a controlled-flow seal between total production fluid pump 16 and the concentrate production stream.
Sucker rod 24 and rod on-off tool 26 are connected to the upper end of pump 20. No-turn tool 28 is installed above lower packer 8 to minimize tubing rotation caused by the operation of the progressing cavity pumps.
Although the invention is described in association with the pumping system set out above, it is to be understood that the invention can be used with any artificial lift system which is compatible with a DHOWS system, for example, electric submersible pumps, beam pumps and gas lift systems.
Liquid separation unit 12 is a conventional downhole water/oil separation system ("DHOWS"). The system is contained within housing 30 and has end units 32, 34.
Liquid/liquid cyclones 36, 38 are positioned in parallel within housing 30. The number of cyclones required will vary depending on the inflow of the well. At the lower end of liquid separation unit 12, axial tubing 40 extends from the underflow outlets cyclones 36, 38 through end unit 34 and lower packer 8 into the area of the well adjacent injection perforations 6. Orifice 42, which regulates total system flow and injection and is sized for flow metering of the injection fluid, is incorporated into axial tubing 40.
At the upper end of liquid separation unit 12, end unit 32 connects the housing 30 to solids separation unit 14. Oil concentrate line 43 extends from the overflow outlet of cyclones 36, 38 through end unit 32 into solids separation unit 14.
Solids separation unit 14, which is shown in detail in Figure 2 is contained within housing 44 and connects to end unit 32 below and to total production fluid pump 16 by means offlanged end unit 46 above. This configuration of end connection geometry and fluid flow paths advantageously allows for solids separator unit 14 to be retrofitted between the total fluid pump and the liquid separation unit in wells previously fitted with a DHOWS system or to be used as an add-on module for newly installed DHOWS systems. The components of solids separation unit 14 include solid/liquid cyclone 48, orifice gallery 50, mixer 52 and solids accumulator 54. Solid/liquid cyclone 48 is located in the upper portion of unit 14. As shown in Figures 1 and 2, the cyclone inlet assembly consists of axial tube 58 extending from one portion of total feed line 17 and which is connected to chamber 60 from which a plurality of axial flow passages 61 lead to inlet section annulus 62. Helical flow diverter 64 is located with inlet section annulus 62 surrounding vortex finder 66. Cone liner 56 is constructed of a material which resists abrasion and which is able to withstand the conditions of field application. A suitable metal or ceramic based material may be used and the preferred material is titanium.
In alternative embodiments, a swirl inducer or static auger, both of which are well known to those skilled in the art, may be used for solids/liquid separation instead of a cyclone separator.
Solids concentrate line 68 extends from the underflow outlet of cyclone 48 to solids tee 70.
Branch line 72 branches from oil concentrate line 43 at mixer 52 and extends downwards to solids tee 70. Solids accumulator 54 is located beneath solids tee 70 and is connected to tee 70 by line 74.
Tee 70 and accumulator 54 are positioned and the line geometry configured so that solids from solid concentrate line 68 and branch line 72 of oil concentrate line 43 drain into accumulator 54 during periods of shutdown.
Orifice gallery 76 which consists of a series of orifice plates 50 sized to reduce the pressure in the solid concentrate to a predetermined amount is situated on solids concentrate line 68. Solids concentrate line 68 and oil concentrate line 43 each extend to oil/solids mixer 52 and oil/solids concentrate line 80 extends from mixer 52 upwards through end unit 46 to oil concentrate pump 20.
As an alternative to orifice gallery 76 and mixer 52, a jet jump or eductor may be used to mix the solids concentrate and the oil concentrate. Figures 11, 12 and 13 show alternative arrangements using orifice gallery 76 and mixer 52, jet pump 90 and progressing cavity pump 92 respectively to mix the solids concentrate and the oil concentrate.
The threaded connections of end unit 32 of desander housing 44 incorporates lugs to provide torque resistance.
Figure 10 is a longitudinal cross sectional view of the solids separation unit of the present invention with an electric submersible pump with a twin motor pump section in a pull-through flow configuration;
Figure 11 is a schematic diagram showing an alternative arrangement using an orifice gallery and mixer for mixing the solids concentrate and oil concentrate streams.
Figures 12 is a schematic diagram showing an alternative arrangement using a jet pump for mixing the solids concentrate and oil concentrate streams.
Figures 13 is a schematic diagram showing an alternative arrangement using a progressing cavity pump for mixing the solids concentrate and oil concentrate streams.
Detailed Description of a Preferred Embodiment of the Invention With reference to Figure 1, well bore casing 2 penetrates the production formation and is provided with production perforations 4 in the area of the production zone to allow for intake of production fluid. Injection perforations 6 in well casing 2 are provided in the area of the injection zone to allow for egress of injection fluid. The injection zone may be above or below the production zone, depending on the well. Lower packer 8 isolates the production zone from the injection zone below. An upper packer (not shown) may be used if the characteristics of the particular well require it.
The well is equipped with artificial lift system 10 of progressing cavity pumps in the upper portion of well casing 2, liquid separation unit 12 in the lower portion of well casing 2, and solids separation unit 14 located between the pumps 10 and liquid separation system 12 and connected to each. Artificial lift system 10 consists of total production fluid pump 16 which is sized to pressurize the injection fluid for injection into the injection zone. Inlet screen 18 is adapted to receive total production fluid into pump 16. Total production feed line 17 extends from pump 16 to solids separation unit 14. Oil concentrate pump 20 is positioned above total production fluid pump 16 and has a capacity of preferably at least 20 m3/d/100rpm. Seal pump 22 provides a controlled-flow seal between total production fluid pump 16 and the concentrate production stream.
Sucker rod 24 and rod on-off tool 26 are connected to the upper end of pump 20. No-turn tool 28 is installed above lower packer 8 to minimize tubing rotation caused by the operation of the progressing cavity pumps.
Although the invention is described in association with the pumping system set out above, it is to be understood that the invention can be used with any artificial lift system which is compatible with a DHOWS system, for example, electric submersible pumps, beam pumps and gas lift systems.
Liquid separation unit 12 is a conventional downhole water/oil separation system ("DHOWS"). The system is contained within housing 30 and has end units 32, 34.
Liquid/liquid cyclones 36, 38 are positioned in parallel within housing 30. The number of cyclones required will vary depending on the inflow of the well. At the lower end of liquid separation unit 12, axial tubing 40 extends from the underflow outlets cyclones 36, 38 through end unit 34 and lower packer 8 into the area of the well adjacent injection perforations 6. Orifice 42, which regulates total system flow and injection and is sized for flow metering of the injection fluid, is incorporated into axial tubing 40.
At the upper end of liquid separation unit 12, end unit 32 connects the housing 30 to solids separation unit 14. Oil concentrate line 43 extends from the overflow outlet of cyclones 36, 38 through end unit 32 into solids separation unit 14.
Solids separation unit 14, which is shown in detail in Figure 2 is contained within housing 44 and connects to end unit 32 below and to total production fluid pump 16 by means offlanged end unit 46 above. This configuration of end connection geometry and fluid flow paths advantageously allows for solids separator unit 14 to be retrofitted between the total fluid pump and the liquid separation unit in wells previously fitted with a DHOWS system or to be used as an add-on module for newly installed DHOWS systems. The components of solids separation unit 14 include solid/liquid cyclone 48, orifice gallery 50, mixer 52 and solids accumulator 54. Solid/liquid cyclone 48 is located in the upper portion of unit 14. As shown in Figures 1 and 2, the cyclone inlet assembly consists of axial tube 58 extending from one portion of total feed line 17 and which is connected to chamber 60 from which a plurality of axial flow passages 61 lead to inlet section annulus 62. Helical flow diverter 64 is located with inlet section annulus 62 surrounding vortex finder 66. Cone liner 56 is constructed of a material which resists abrasion and which is able to withstand the conditions of field application. A suitable metal or ceramic based material may be used and the preferred material is titanium.
In alternative embodiments, a swirl inducer or static auger, both of which are well known to those skilled in the art, may be used for solids/liquid separation instead of a cyclone separator.
Solids concentrate line 68 extends from the underflow outlet of cyclone 48 to solids tee 70.
Branch line 72 branches from oil concentrate line 43 at mixer 52 and extends downwards to solids tee 70. Solids accumulator 54 is located beneath solids tee 70 and is connected to tee 70 by line 74.
Tee 70 and accumulator 54 are positioned and the line geometry configured so that solids from solid concentrate line 68 and branch line 72 of oil concentrate line 43 drain into accumulator 54 during periods of shutdown.
Orifice gallery 76 which consists of a series of orifice plates 50 sized to reduce the pressure in the solid concentrate to a predetermined amount is situated on solids concentrate line 68. Solids concentrate line 68 and oil concentrate line 43 each extend to oil/solids mixer 52 and oil/solids concentrate line 80 extends from mixer 52 upwards through end unit 46 to oil concentrate pump 20.
As an alternative to orifice gallery 76 and mixer 52, a jet jump or eductor may be used to mix the solids concentrate and the oil concentrate. Figures 11, 12 and 13 show alternative arrangements using orifice gallery 76 and mixer 52, jet pump 90 and progressing cavity pump 92 respectively to mix the solids concentrate and the oil concentrate.
The threaded connections of end unit 32 of desander housing 44 incorporates lugs to provide torque resistance.
The operation of the invention will now be described with reference to Figures 1, 2 and 3.
It is to be noted that Figure 3 is a simplified schematic only and does not illustrate all of the features shown in Figure 1. Production fluid enters well casing 2 via production perforations 4. The fluid enters total fluid (emulsion) pump 16 through inlet screen 18 and is pumped into total fluid feed line 17. The fluid then enters chamber 60 and passes through axial flow passages 61 into inlet section annulus 62. The direction of flow of the liquid is changed from axial to tangential by flow diverter 64. The fluid then passes into cyclone 48 wherein a solids depleted stream consisting mostly ofwater and oil exits cyclone 48 via its overflow outlet and, being contained by housing 44, descends to the inlet of liquid/liquid cyclone 36. The solids enriched stream which normally contains high concentrations of sand, exits from the underflow outlet of cyclone 48 and passes through solids concentrate line 68 to mixer 52. The pressure of the stream is reduced as it passes through orifice plate unit 50 so that the pressure matches the pressure of the oil concentrate stream with which it eventually commingles at mixer 52.
The solids depleted stream enters liquid/liquid cyclone 36 where it is separated into an oil concentrate stream and a water stream. The oil concentrate stream exits cyclone 36 (and 38 according to Figure 2 which shows upper and lower cyclones) at the overflow outlet and is directed through oil concentrate line to mixer where it mixes with solid enriched stream. The mixed oil and solids stream is then transported through oil/solids concentrate line 80 to oil concentrate pump 20 and then pumped to surface. The water stream, now substantially free of solids, exits cyclone 36 through the underflow outlet and is reinjected into injection zone through injection perforations 6.
The separator system of the present invention can be used with either a push through or pull through DHOWS system. In pull through systems, the solid/liquid mixture is pulled through the solid/liquid hydrocyclone prior to entering the pump suction of the DHOWS
system. These configurations are typically utilized when there is concern that boosting the pressure up to the injection pressure requirements of the DHOWS system, prior to passing the solid/liquid mixture through the solid/liquid hydrocyclone, could cause emulsions to form which cannot be separated within the solid/liquid and/or liquid/liquid hydrocyclones thus rendering the entire system inoperable.
In push through systems, the solid/liquid mixture is passed through the DHOWS
pumps prior to the solid/liquid hydrocyclone. This increases the solid/liquid mixture pressure to that required for water injection. Following the increase in pressure, the solid/liquid mixture is directed to the solid/liquid hydrocyclone for separation. Push through systems are typically utilized in situations where shearing the solid/liquid mixture in the DHOWS pumps prior to solid/liquid separation does not cause a concern of emulsions forming that cannot be readily separated in the solid/liquid hydrocyclone and/or liquid/liquid cyclone.
Referring now to Figure 6, the solids separation unit of the present invention with a progressing cavity pump in a push through flow configuration is shown. Figure 7 shows the solids separation unit of the present invention with an electric submersible pump 94 with a single shaft pump section in a push-through flow configuration. Figure 8 shows the solids separation unit of the present invention with an electric submersible pump 96 with a twin shaft pump section in a push-through flow configuration. Figure 9 shows the solids separation unit of the present invention with a high volume electric submersible pump (98) with a twin shaft pump section (99) in a pull-through flow configuration. Figure 10 shows the solids separation unit of the present invention with an electric submersible pump (98) with a twin motor pump section (100,102) in a pull-through flow configuration;
Example 1 The separation system of the present invention was tested in field trials conducted in a well of the Hayter Dina "Q" pool oil reservoir in Alberta, Canada. The reservoir is comprised of clean unconsolidated channel fill sands deposited in a fluvial to estuarine environment. The Hayter Dina "Q" pool is a heavy oil pool (14-16 API) with a large and very active water drive.
The well chosen had been previously used for testing of a DHOWS system without solids separation and had exhibited severe injection zone plugging. Figure 5 shows a plot of the pressures and rates monitored during the previous operation of the conventional DHOWS
system (without solids separation). The data shows that the injectivity began to decline shortly after the trial began, to the point where the injection pressure exceeded the rated pressure of the total flow pump. As a result, only limited drawdown of the well was achieved. At this low drawdown, the oil production remained below 2 m3/d for the majority of the trial period.
In the field trial of the system of the present invention (DHOWS with solids separation), the well was equipped with a BMW Pump mode1120-600 total fluid pump, a BMW Pump mode120-600 oil concentrate pump, and a BMW Pump model 4-600 seal pump. The solids separator was a single cyclone liner with a capacity of up to 400 m3/d and up to 1% sand by volume.
In preparation for installation of the DHOWS with solid separation system, the well bore was cleaned of sand using a sand bailer and a pump-to-surface tool. An injection test was performed to confirm the injection rate into the lower disposal zone. To operate the lower total emulsion pump at optimal efficiency and to inject the desired 200-250 m3/d of water into the injection zone, an injectivity index of greater than or equal to 0.2 m3/d/kPa was achieved.
A retrievable packer was set between the production and the injection intervals to isolate the zones. An extended seal assembly was chosen to allow axial tubing movement while maintaining annulus isolation. The system was installed in two sections. The first section consisted of the solids and liquid separation systems, instrumentation sub and no-turn tool. The pump intake, total fluid pump, sealing pump, concentrate production pump and rod on-off connector made-up the second section. Both sections were assembled on location and run into the well bore.
The rod on-off connector consisted of a J-lock mechanism designed to allow the corod string to be disconnected from the rotor assembly. Following the running and landing of the downhole separation unit, a 25.4 mm corod string was run and latched on to the BMW 16-600 rotor assembly. A 60 hp electric wellhead drive was installed to operate the separation system from the surface.
The separation system was initially operated at a low pump speed (200 rpm).
The speed was increased by 25 to 50 rpm every two weeks up to a final speed of 375 rpm.
The performance results of the Hayter field trial are shown in Figures 4a and 4b. The results illustrate that the following:
It is to be noted that Figure 3 is a simplified schematic only and does not illustrate all of the features shown in Figure 1. Production fluid enters well casing 2 via production perforations 4. The fluid enters total fluid (emulsion) pump 16 through inlet screen 18 and is pumped into total fluid feed line 17. The fluid then enters chamber 60 and passes through axial flow passages 61 into inlet section annulus 62. The direction of flow of the liquid is changed from axial to tangential by flow diverter 64. The fluid then passes into cyclone 48 wherein a solids depleted stream consisting mostly ofwater and oil exits cyclone 48 via its overflow outlet and, being contained by housing 44, descends to the inlet of liquid/liquid cyclone 36. The solids enriched stream which normally contains high concentrations of sand, exits from the underflow outlet of cyclone 48 and passes through solids concentrate line 68 to mixer 52. The pressure of the stream is reduced as it passes through orifice plate unit 50 so that the pressure matches the pressure of the oil concentrate stream with which it eventually commingles at mixer 52.
The solids depleted stream enters liquid/liquid cyclone 36 where it is separated into an oil concentrate stream and a water stream. The oil concentrate stream exits cyclone 36 (and 38 according to Figure 2 which shows upper and lower cyclones) at the overflow outlet and is directed through oil concentrate line to mixer where it mixes with solid enriched stream. The mixed oil and solids stream is then transported through oil/solids concentrate line 80 to oil concentrate pump 20 and then pumped to surface. The water stream, now substantially free of solids, exits cyclone 36 through the underflow outlet and is reinjected into injection zone through injection perforations 6.
The separator system of the present invention can be used with either a push through or pull through DHOWS system. In pull through systems, the solid/liquid mixture is pulled through the solid/liquid hydrocyclone prior to entering the pump suction of the DHOWS
system. These configurations are typically utilized when there is concern that boosting the pressure up to the injection pressure requirements of the DHOWS system, prior to passing the solid/liquid mixture through the solid/liquid hydrocyclone, could cause emulsions to form which cannot be separated within the solid/liquid and/or liquid/liquid hydrocyclones thus rendering the entire system inoperable.
In push through systems, the solid/liquid mixture is passed through the DHOWS
pumps prior to the solid/liquid hydrocyclone. This increases the solid/liquid mixture pressure to that required for water injection. Following the increase in pressure, the solid/liquid mixture is directed to the solid/liquid hydrocyclone for separation. Push through systems are typically utilized in situations where shearing the solid/liquid mixture in the DHOWS pumps prior to solid/liquid separation does not cause a concern of emulsions forming that cannot be readily separated in the solid/liquid hydrocyclone and/or liquid/liquid cyclone.
Referring now to Figure 6, the solids separation unit of the present invention with a progressing cavity pump in a push through flow configuration is shown. Figure 7 shows the solids separation unit of the present invention with an electric submersible pump 94 with a single shaft pump section in a push-through flow configuration. Figure 8 shows the solids separation unit of the present invention with an electric submersible pump 96 with a twin shaft pump section in a push-through flow configuration. Figure 9 shows the solids separation unit of the present invention with a high volume electric submersible pump (98) with a twin shaft pump section (99) in a pull-through flow configuration. Figure 10 shows the solids separation unit of the present invention with an electric submersible pump (98) with a twin motor pump section (100,102) in a pull-through flow configuration;
Example 1 The separation system of the present invention was tested in field trials conducted in a well of the Hayter Dina "Q" pool oil reservoir in Alberta, Canada. The reservoir is comprised of clean unconsolidated channel fill sands deposited in a fluvial to estuarine environment. The Hayter Dina "Q" pool is a heavy oil pool (14-16 API) with a large and very active water drive.
The well chosen had been previously used for testing of a DHOWS system without solids separation and had exhibited severe injection zone plugging. Figure 5 shows a plot of the pressures and rates monitored during the previous operation of the conventional DHOWS
system (without solids separation). The data shows that the injectivity began to decline shortly after the trial began, to the point where the injection pressure exceeded the rated pressure of the total flow pump. As a result, only limited drawdown of the well was achieved. At this low drawdown, the oil production remained below 2 m3/d for the majority of the trial period.
In the field trial of the system of the present invention (DHOWS with solids separation), the well was equipped with a BMW Pump mode1120-600 total fluid pump, a BMW Pump mode120-600 oil concentrate pump, and a BMW Pump model 4-600 seal pump. The solids separator was a single cyclone liner with a capacity of up to 400 m3/d and up to 1% sand by volume.
In preparation for installation of the DHOWS with solid separation system, the well bore was cleaned of sand using a sand bailer and a pump-to-surface tool. An injection test was performed to confirm the injection rate into the lower disposal zone. To operate the lower total emulsion pump at optimal efficiency and to inject the desired 200-250 m3/d of water into the injection zone, an injectivity index of greater than or equal to 0.2 m3/d/kPa was achieved.
A retrievable packer was set between the production and the injection intervals to isolate the zones. An extended seal assembly was chosen to allow axial tubing movement while maintaining annulus isolation. The system was installed in two sections. The first section consisted of the solids and liquid separation systems, instrumentation sub and no-turn tool. The pump intake, total fluid pump, sealing pump, concentrate production pump and rod on-off connector made-up the second section. Both sections were assembled on location and run into the well bore.
The rod on-off connector consisted of a J-lock mechanism designed to allow the corod string to be disconnected from the rotor assembly. Following the running and landing of the downhole separation unit, a 25.4 mm corod string was run and latched on to the BMW 16-600 rotor assembly. A 60 hp electric wellhead drive was installed to operate the separation system from the surface.
The separation system was initially operated at a low pump speed (200 rpm).
The speed was increased by 25 to 50 rpm every two weeks up to a final speed of 375 rpm.
The performance results of the Hayter field trial are shown in Figures 4a and 4b. The results illustrate that the following:
(i) injectivity The injectivity did not decline as a result of sand plugging as in the operation of the DHOWS without solids separation in the same well.
(ii) surface sand cuts The surface sand cuts showed the presence of solids, ranging from 0.1% to 0.7%
indicating that the separation system was effective.
(iii) improved drawdown The system was successful in drawing down the well and maintaining oil rates above 6 m3/d . The total volume of fluid produced to surface is 60 m3/d with approximately 300 m3/d of separated water injected into the lower disposal zone, indicated an 83% reduction in water to surface.
While the invention has been described with reference to certain embodiments, it is to be understood that the description is made only by way of example and that the invention is not to be limited to the particular embodiments described herein and that variations and modifications may be implemented without departing from the scope of the invention as defined in the claims hereinafter set out.
(ii) surface sand cuts The surface sand cuts showed the presence of solids, ranging from 0.1% to 0.7%
indicating that the separation system was effective.
(iii) improved drawdown The system was successful in drawing down the well and maintaining oil rates above 6 m3/d . The total volume of fluid produced to surface is 60 m3/d with approximately 300 m3/d of separated water injected into the lower disposal zone, indicated an 83% reduction in water to surface.
While the invention has been described with reference to certain embodiments, it is to be understood that the description is made only by way of example and that the invention is not to be limited to the particular embodiments described herein and that variations and modifications may be implemented without departing from the scope of the invention as defined in the claims hereinafter set out.
Claims (14)
1. A method for separating downhole oil well production fluid from a production zone of a subterranean formation, wherein said fluid contains oil, water and solids comprising:
(a) delivering the production fluid to a liquid/solid cyclone;
(b) separating the production fluid in the liquid/solid cyclone into a solids enriched stream at a cyclone underflow and a oil and water enriched stream at a cyclone overflow;
(c) delivering the oil and water enriched stream to a liquid/liquid cyclone;
and (d) separating the oil and water enriched stream in the liquid/liquid cyclone into an oil enriched stream at the cyclone overflow and a water enriched stream at the cyclone underflow.
(a) delivering the production fluid to a liquid/solid cyclone;
(b) separating the production fluid in the liquid/solid cyclone into a solids enriched stream at a cyclone underflow and a oil and water enriched stream at a cyclone overflow;
(c) delivering the oil and water enriched stream to a liquid/liquid cyclone;
and (d) separating the oil and water enriched stream in the liquid/liquid cyclone into an oil enriched stream at the cyclone overflow and a water enriched stream at the cyclone underflow.
2. The method of claim 1 wherein the enriched water stream is reinjected into a downhole disposal site located either above or below the production zone.
3. The method of claim 1 or 2 wherein the oil enriched stream is delivered to surface.
4. The method of claim 1, 2 or 3 wherein the solids enriched stream is delivered to surface.
5. The method of claim 1, 3 or 4 wherein the oil enriched stream and the solids enriched stream are mixed downhole and said mixture is delivered to surface.
6. The method of claim 5 wherein a pressure reducing means reduces the pressure of the solid enriched stream to approximately equal to the pressure of the oil enriched stream prior to mixing said streams.
7. The method of claim 6 wherein the pressure reducing means is an orifice gallery.
8. The method of claim 5 or 6 wherein the oil enriched stream and the solid enriched stream are mixed by a jet pump.
9. The method of claim 5 or 6 wherein the oil enriched stream and the solid enriched stream are mixed by a progressing cavity pump.
10. A method for separating downhole oil well production fluid from a production zone of a subterranean formation, wherein said fluid contains oil, water and solids comprising:
(a) delivering the production fluid to a liquid/solid separator;
(b) separating the production fluid in the liquid/solid separator into a solids enriched stream and an oil and water enriched stream;
(c) delivering the oil and water enriched stream to a liquid/liquid cyclone separator; and (d) separating the oil and water enriched stream in the liquid/liquid cyclone separator into an oil enriched stream at a cyclone overflow and a water enriched stream at a cyclone underflow.
(a) delivering the production fluid to a liquid/solid separator;
(b) separating the production fluid in the liquid/solid separator into a solids enriched stream and an oil and water enriched stream;
(c) delivering the oil and water enriched stream to a liquid/liquid cyclone separator; and (d) separating the oil and water enriched stream in the liquid/liquid cyclone separator into an oil enriched stream at a cyclone overflow and a water enriched stream at a cyclone underflow.
11. The method of claim 10 wherein the liquid/solid separator is a swirl inducer.
12. The method of claim 11 wherein the liquid/solid separator is a static auger.
13. An apparatus for separating oil well production fluid containing oil, water and solids downhole comprising:
(a) at least one liquid/solid cyclone adapted to receive the production fluid and separate it into a solid enriched stream at an underflow outlet of said cyclone and an oil and water enriched stream at an overflow outlet of said cyclone;
(b) at least one liquid/liquid cyclone adapted to receive the oil and water enriched stream as overflow from the liquid/solid cyclone and separate said stream into an oil enriched stream at an overflow outlet of said cyclone and a water enriched stream at an underflow outlet of said cyclone;
(c) a mixing means to mix the oil enriched stream with the solids enriched stream and produce an oil/solids stream;
(d) a first duct means to transport the oil enriched stream from the underflow outlet of the liquid/liquid cyclone to the mixing means;
(e) a second duct means to transport the solid enriched stream to the mixing means; and (f) a third duct means to transport the oil/solids stream to surface.
(a) at least one liquid/solid cyclone adapted to receive the production fluid and separate it into a solid enriched stream at an underflow outlet of said cyclone and an oil and water enriched stream at an overflow outlet of said cyclone;
(b) at least one liquid/liquid cyclone adapted to receive the oil and water enriched stream as overflow from the liquid/solid cyclone and separate said stream into an oil enriched stream at an overflow outlet of said cyclone and a water enriched stream at an underflow outlet of said cyclone;
(c) a mixing means to mix the oil enriched stream with the solids enriched stream and produce an oil/solids stream;
(d) a first duct means to transport the oil enriched stream from the underflow outlet of the liquid/liquid cyclone to the mixing means;
(e) a second duct means to transport the solid enriched stream to the mixing means; and (f) a third duct means to transport the oil/solids stream to surface.
14. The apparatus of claim 13 wherein a solids accumulator provided is connected to the first duct means and the second duct means to receive solids draining from said first and second duct means.
Priority Applications (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002247838A CA2247838C (en) | 1998-09-25 | 1998-09-25 | Downhole oil/water separation system with solids separation |
| US09/405,138 US6189613B1 (en) | 1998-09-25 | 1999-09-24 | Downhole oil/water separation system with solids separation |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002247838A CA2247838C (en) | 1998-09-25 | 1998-09-25 | Downhole oil/water separation system with solids separation |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2247838A1 CA2247838A1 (en) | 2000-03-25 |
| CA2247838C true CA2247838C (en) | 2007-09-18 |
Family
ID=4162837
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002247838A Expired - Fee Related CA2247838C (en) | 1998-09-25 | 1998-09-25 | Downhole oil/water separation system with solids separation |
Country Status (2)
| Country | Link |
|---|---|
| US (1) | US6189613B1 (en) |
| CA (1) | CA2247838C (en) |
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Also Published As
| Publication number | Publication date |
|---|---|
| US6189613B1 (en) | 2001-02-20 |
| CA2247838A1 (en) | 2000-03-25 |
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| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request | ||
| MKLA | Lapsed | ||
| MKLA | Lapsed |
Effective date: 20110926 |