EP2716862A1 - Procédé et appareil de production d'hydrocarbures à partir d'un système multicouche - Google Patents

Procédé et appareil de production d'hydrocarbures à partir d'un système multicouche Download PDF

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Publication number
EP2716862A1
EP2716862A1 EP12187691.6A EP12187691A EP2716862A1 EP 2716862 A1 EP2716862 A1 EP 2716862A1 EP 12187691 A EP12187691 A EP 12187691A EP 2716862 A1 EP2716862 A1 EP 2716862A1
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EP
European Patent Office
Prior art keywords
injectant
oil
layer
combustion
injectants
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP12187691.6A
Other languages
German (de)
English (en)
Inventor
Klaus Bent Hasbo
Finn Engstrøm
Willem Schulte
Wim Van Vark
Pieter Karel Anton Kapteijn
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Total E&P Danmark AS
Original Assignee
Maersk Olie og Gas AS
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Maersk Olie og Gas AS filed Critical Maersk Olie og Gas AS
Priority to EP12187691.6A priority Critical patent/EP2716862A1/fr
Priority to EP13783497.4A priority patent/EP2904197A2/fr
Priority to PCT/EP2013/070983 priority patent/WO2014056946A2/fr
Publication of EP2716862A1 publication Critical patent/EP2716862A1/fr
Priority to DKPA201470330A priority patent/DK178646B1/en
Withdrawn legal-status Critical Current

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    • 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
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • 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
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/164—Injecting CO2 or carbonated water
    • 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
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium

Definitions

  • the invention relates to method for producing hydrocarbons from a multilayer system, and an apparatus for use in such a method.
  • An alternative method is to use gas to displace oil.
  • gas to displace oil.
  • the availability of large volumes of pressurized gas is limited, making the method relatively expensive. It may also be troublesome to maintain the pressure once a major part of the oil is recovered, and collapse of the field structure may also become a problem.
  • not all gasses are suitable or desirable to have injected into an oil field. Nitrogen gas is fairly inert but is relatively expensive to obtain. Oxygen as a pure gas leads to combustion hazard when combined with flammable materials such as oil and methane gas.
  • Another known method is to re-inject the natural gas (mostly consisting of methane) produced from the oil field.
  • Combined methods include water-alternating-gas (WAG) which uses intermittent injection of water and gas, and SWAG wherein water and gas are injected simultaneously or sequentially.
  • WAG water-alternating-gas
  • SWAG wherein water and gas are injected simultaneously or sequentially.
  • Carbon dioxide is a favoured gas to inject in the WAG method.
  • Such methods are believed to yield 5-10% recovery improvement under favourable conditions, compared to continuous water injection.
  • the invention relates to a method for producing oil from a multilayer system, wherein the multilayer system comprises at least one high permeable layer and at least one low permeable layer, wherein the high permeable layer is adjacent to the low permeable layer, wherein a first injectant is injected into the high permeable layer and simultaneously a second injectant is injected into the low permeable layer, wherein oil replaced by the first and second injectants from the high and low permeable layers is collected.
  • the permeability of the high permeable layer is at least a factor 2, preferably a factor 3 or 4, higher than the low permeable layer, as measured in millidarcy (mD) at the operating pressure and temperature for the first or the second injectant.
  • MD millidarcy
  • the multilayer may consist of only two adjacent layers, or multiple stacked layers of different consistency.
  • a relatively low permeable layer may be above a relatively high permeable layer, but it is also possible that the relatively high permeable layer is above a relatively low permeable layer.
  • the difference between a relatively high and a relatively low permeable layer would be at least an order of magnitude 2 as measured in millidarcy (mD), preferably at least 3 to 4 orders of magnitude under the operating conditions as selected.
  • the contrast between the high and low permeable layer is within 2-40 orders of magnitude, more preferably within 2-10 orders of magnitude.
  • the amount of cross-leaking of injectants between the low and high permeable layers will depend on the nature of the layers in a given situation.
  • the layers can be essentially horizontal but in practice are often inclined or arched.
  • the injectants can be in various fluid phases. Liquid and gaseous injectants relate to the physical state of the injectant at atmospheric pressure; many gaseous injections would become liquid, dense phase or supercritical fluid under the pressures that may occur at great depths, which may lead to a significant change in the viscosity of the injectants.
  • the first injectant has a higher viscosity than the second injectant. This makes it easier to control the progress of the front of the first and second injectants to displace oil. Viscosity may be controlled by selection of the injectant or mixture of injectants, for instance water, carbon dioxide, or nitrogen. The viscosity of injectants can be adjusted, for instance by adding surfactants, polymers or other additives.
  • the points of injection for the first and second injectant are adjacent to each other in the horizontal plane.
  • Injection positions can be arranged in various different arrangements, depending on the specific parameters of a certain location. For optimal control, the injection positions are preferably closely grouped together. It is preferred if the rate of injection of injectants for the high and low permeable layers is monitored and adjusted to keep the fronts of replacement of oil from the high and low permeable layers within predetermined limits. It was found that keeping the flood fronts relatively close to each other, a higher oil recovery is achieved. It is postulated that a piston-like displacement of the oil can be achieved if the flood front controlled by the injectants in adjacent layers progresses simultaneously. Preferably, the progress of the fronts of displacement of oil in the high and low permeable layers is monitored through seismic or volumetric methods.
  • the rate of injection is adjusted to keep the front of replacement for the liquid injectant essentially ahead of the gaseous injectant. This was found to yield better results than cases where the gaseous injectant is ahead of the liquid injectant.
  • At least one of the first and/or second injectants comprises a combustion product from natural gas or oil.
  • Such combustion products are often considered waste, and it is cost effective to re-use such waste products.
  • at least part of the combustion product is obtained by combustion of gas and/or oil produced from the first and/or second layer. This ensures a supply of injectant is readily available at the site, making the method less dependent on external supplies.
  • the combustion product is CO 2 used as a gaseous injectant.
  • CO 2 is one of the main combustion products obtained from hydrocarbons, along with water, and it is an excellent gas for recovering oil.
  • the injecting of CO 2 prevents the gas from entering the atmosphere and contributes to global green house effects.
  • the combustion product may also comprises water that can be used as an injectant.
  • the first and/or second injectant is selected from CO 2 , N 2 or mixtures thereof.
  • Carbon dioxide and nitrogen gas as suitable gases for oil recovery.
  • Nitrogen may be obtained in large quantities by air separation methods.
  • the second injectant comprises N 2 obtained from an air separation method, and wherein O 2 from the same air separation method is used in the combustion of natural gas and oil produced, to yield water and CO 2 .
  • all products from the air separation method are used in other useful method, yielding water, and carbon dioxide from combustion, and nitrogen gas from the air separation method.
  • useful energy is generated in the same process. This makes the method at least partially self-sufficient, which is a great advantage in the remote areas oil recovery may take place.
  • the second injectant is an essentially aqueous injectant.
  • Water may for instance be obtained from a water supply, water production or from a combustion method as described above.
  • the aqueous injectant may comprise other compounds in addition to water, such as surfactants, polymers and other chemicals that may alter the properties, for instance the flow properties under high pressure.
  • the salinity of the aqueous injectant is lowered by the addition of low salinity water.
  • Reduction of the salinity of production water gives a significant effect in improved oil production.
  • Water with a salinity lower than the water present in the oil reservoir showed an improved oil recovery, which is postulated to stem from the improved capability to form oil-in-water of aqueous solutions having a lower salt or ion content.
  • Mixing low salinity water with produced water lowers the overall salinity, and significant effects were found even when amounts as low as 10% w/w of lower salinity water is added.
  • Low salinity water could for instance be distilled water or water treated in other ways to lower its dissolved salt content.
  • a convenient and efficient way to obtain low salinity water is to capture the water produced in the combustion of hydrocarbons recovered on the production site, collected for instance by a distillation/condensation method.
  • Preferably, at least part of the low salinity water is obtained as a combustion product of natural gas and oil recovered.
  • the viscosity of the first and/or second injectant is controlled by adjusting the temperature.
  • Temperature is a convenient way of fine-tuning the viscosity of an injectant, and offers a relatively simple way of controlling the progress of fluid fronts in the layers.
  • hot water for example, has a viscosity of from 0.2 to 0.3, whereas the cold water has a viscosity of from 0.9 to 1 cp.
  • the viscosity can be adjusted by a factor of 2-5 times. Similar viscosity adjustments can also be made for other injectants such as carbon dioxide or nitrogen.
  • at least part of the heat to control the temperature of the first and/or second injectant is obtained from the combustion of natural gas and/or oil, more preferably oil and/or gas produced by the process.
  • the invention also provides an apparatus for use in the method as described herein, comprising at least one first injector for injecting a first essentially liquid injectant into a first layer, at least one second injector for injecting a second essentially gaseous injectant into a second layer adjacent to the first layer, monitoring means for monitoring the progress of injection for the first and second injectants, and adjusting means coupled to the monitoring means and the first and second injectors.
  • This apparatus is particularly suitable to perform the method as described above. The rate of injection of injectants for the high and low permeable layers is monitored and adjusted to keep the fronts of displacement of oil from the high and low permeable layers within predetermined limits.
  • the monitoring means could for instance comprise temperature, pressure, chemical, flow, and acoustic analysis, monitoring both the injection positions and the production well using techniques such as chemical tracers, observation wells and/or seismic contrasting.
  • Preferred monitoring methods include surveillance by direct observation using seismic methods or surveillance wells; or indirectly through volumetrics, tracers and methods analyzing the pressure drop at production and/or injection wells.
  • the adjusting means could include valves and regulators for controlling the pressure and throughput of the first and second injectants. It is possible to adjust both the first and second injectants, but it is preferred if one of the first and second injectants is kept at a constant rate and the other injectant is varied depending on the monitored signals.
  • the monitoring means and adjusting means can be manually controlled, but are preferably automated.
  • the adjusting means are programmed to keep the progression of the first and second injectant within predetermined limits.
  • the progression of the displacement front of the first and second injectant are kept within 10% as measured by volume.
  • the apparatus comprises a combustion unit, wherein an outlet for CO 2 produced by the combustion is coupled to the second injector, and wherein an outlet for water produced by the combustion is coupled to the first injector.
  • Figure 1 schematically shows the method according to the invention.
  • the figure shows a multilayer system 1, comprising an upper layer 2 and a lower layer 3.
  • the upper layer has a relatively high permeability/low density
  • the lower layer has a relatively low permeability/high density.
  • the relative vertical position of the relatively high and low permeable layers could also be inverted. It is also possible to have multiple alternating layers.
  • the adjacent layers 2,3 are in communication; fluids may migrate from one layer into the other through the interface 4 between the layers. By injecting a liquid such as water, into the lower layer 5, oil is displaced through the layer in the displacement direction indicated by the arrows.
  • a gaseous injectant 6 such as carbon dioxide, nitrogen gas or a mixture thereof is injected into the upper layer 2.
  • the front of the liquid injectant 7 does not necessarily run at the same rate as the gaseous injectant 8.
  • the difference 9 in progress should however be controlled and kept within predetermined limits, dependent on the parameters of a specific field. Oil from the multilayer system is pushed towards the one or more production pipes 10, where the oil is collected and transported towards the surface 11.
  • the production pipes may also comprise vertical or angled pipes, as known in the art.
  • Figure 2 shows a system 20 that can be used for the supply of injectants for the method described in figure 1 .
  • the system comprises an air separation unit 21, that separates incoming air 22 into its main components, nitrogen gas 23 and oxygen 24.
  • the nitrogen gas may be used as an injectant.
  • the oxygen 24 is used to a combustion unit 25 that combusts fuel 26 that may be comprise oil and gas derived from an oil production method, in particular the method as described in figure 1 .
  • the combustion unit 25 produces energy 27, as well as carbon dioxide 28 and water 29, that may be used as injectants for the method described in figure 1 .
  • the produced injectants Before the produced injectants can be used in the method as described herein, they may be subject to further processing, such as mixing with other injectants, compression or decompression to achieve the desired pressure, and cooling or heating to achieve the desired temperature.
  • FIG. 3 shows a method 30, wherein an air separator unit 31 separates air 32 into nitrogen gas 32 and oxygen 33.
  • the oxygen is used in a combustion unit 34 to combust fuel 35, yielding energy 36, water 37 and carbon dioxide 38 as main products.
  • the water 37 from the combustion unit is lead to a first injector unit 39.
  • the injector unit 39 the water is brought under the desired temperature and pressure.
  • the combustion water 37 is mixed with additional liquids 40, such as additional water or other liquids and/or flow-affecting compounds such as surfactants.
  • the liquid is injected into a first oil-containing layer 41 to displace oil and/or gas.
  • Carbon dioxide 38 and/or nitrogen gas 32 are brought to a second injector unit 42.
  • the gaseous injectants are mixed and brought under the desired temperature and pressure.
  • additional gases 43 are added from external sources, such as additional carbon dioxide and/or nitrogen gas.
  • the gaseous injectants are then injected into a second oil-containing layer 44 to displace oil and/or gas.
  • the oil and/or gas displaced from the first and second layers 41, 44 is then collected at a distance from the injector positions through one or more oil wells 45 to a collector unit 46. From the collector unit 46, part of the collected oil and/or gas is transported away as produced gas and/or oil 47. Optionally, part of the produced hydrocarbons is lead to the combustion unit 34 as fuel 35.
  • FIG. 4 schematically shows a system 50 for controlling a method as shown in figure 1 and 3 , to control the progress of hydrocarbon displacement in multiple simultaneously producing layers.
  • a control unit 51 receives input from monitoring sensors of the first injector 52 that regulates the injecting of a first gaseous or liquid injectant into a first layer, and a second injector 53 that regulates the injecting of a second gaseous or liquid injectant into a second layer.
  • the control unit 51 also receives external monitoring data 54, for instance pressure variations from the production well and injection well, using techniques such as chemical tracers, observation wells and/or seismic monitoring.
  • the control unit compares the progress of the injectants in the first and second layers.
  • the control units instruct an adjusting unit 55 to adjust the injection ratio of the first injector 52 and the second injector 53. This may be done by raising the rate of injection for the layer that lags behind, or lowering the injection rate for the layer that runs in front, or a combination of these adjustments. For ease of controls it is preferred if the rate of injection is kept constant for one layer and the other layer is adjusted. This system 50 can be extended to control run for more than 2 injectors 42, 53 simultaneously.
  • Figure 5 describes examples of flow profiles that may be used in the method.
  • Figure 5a shows a sequential injection profile, schematically showing the injected volumes of injectants over time.
  • the time scale for this method is typically weeks, months or years.
  • the upper line 60 shows a first injectant, whereas the lower line 61 shows a second injectant.
  • the injectants are injected intermittently, in a predetermined sequence.
  • the injectants may for instance be water, aqueous polymer solutions, nitrogen or carbon dioxide.
  • Figure 5b shows a simultaneous injection profile, schematically showing the injected volumes of injectants over time.
  • the upper line 62 shows a first injectant, whereas the lower line 63 shows a second injectant.
  • the injectants are injected simultaneously.
  • Figure 5c shows an alternative simultaneous injection profile, schematically showing the injected volumes of injectants over time.
  • the upper line 64 shows a first injectant
  • the lower line 65 shows a second injectant.
  • the injectants are injected simultaneously.
  • For the second injectant 65 a larger volume is injected in the second injection interval 67 relative to the first injection interval.

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  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
  • Physical Or Chemical Processes And Apparatus (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
EP12187691.6A 2012-10-08 2012-10-08 Procédé et appareil de production d'hydrocarbures à partir d'un système multicouche Withdrawn EP2716862A1 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
EP12187691.6A EP2716862A1 (fr) 2012-10-08 2012-10-08 Procédé et appareil de production d'hydrocarbures à partir d'un système multicouche
EP13783497.4A EP2904197A2 (fr) 2012-10-08 2013-10-08 Procédé et appareil de production d'hydrocarbures à partir d'un système multicouches
PCT/EP2013/070983 WO2014056946A2 (fr) 2012-10-08 2013-10-08 Procédé et appareil de production d'hydrocarbures à partir d'un système multicouches
DKPA201470330A DK178646B1 (en) 2012-10-08 2014-06-04 Method and apparatus for producing hydrocarbons from a multilayer system

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP12187691.6A EP2716862A1 (fr) 2012-10-08 2012-10-08 Procédé et appareil de production d'hydrocarbures à partir d'un système multicouche

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EP2716862A1 true EP2716862A1 (fr) 2014-04-09

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EP12187691.6A Withdrawn EP2716862A1 (fr) 2012-10-08 2012-10-08 Procédé et appareil de production d'hydrocarbures à partir d'un système multicouche
EP13783497.4A Withdrawn EP2904197A2 (fr) 2012-10-08 2013-10-08 Procédé et appareil de production d'hydrocarbures à partir d'un système multicouches

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DK (1) DK178646B1 (fr)
WO (1) WO2014056946A2 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN104453806A (zh) * 2014-10-30 2015-03-25 中国石油化工股份有限公司 一种注氮气解除砂岩凝析气藏水锁的方法

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CA3129850C (fr) 2019-02-14 2024-01-02 Total Se Procede de recuperation de petrole amelioree

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20030220750A1 (en) * 2002-05-24 2003-11-27 Jean-Perre Delhomme methods for monitoring fluid front movements in hydrocarbon reservoirs using permanent sensors
EP2239415A1 (fr) * 2009-04-09 2010-10-13 Shell Internationale Research Maatschappij B.V. Récupération d'huile améliorée à l'aide de mousse dans un réservoir d'huile à couches
US20110146978A1 (en) * 2009-12-17 2011-06-23 Greatpoint Energy, Inc. Integrated enhanced oil recovery process

Family Cites Families (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2734578A (en) * 1956-02-14 Walter
FR2911629A1 (fr) * 2007-01-19 2008-07-25 Air Liquide Procede d'extraction de produits petroliferes au moyen de fluides d'aide a l'extraction

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20030220750A1 (en) * 2002-05-24 2003-11-27 Jean-Perre Delhomme methods for monitoring fluid front movements in hydrocarbon reservoirs using permanent sensors
EP2239415A1 (fr) * 2009-04-09 2010-10-13 Shell Internationale Research Maatschappij B.V. Récupération d'huile améliorée à l'aide de mousse dans un réservoir d'huile à couches
US20110146978A1 (en) * 2009-12-17 2011-06-23 Greatpoint Energy, Inc. Integrated enhanced oil recovery process

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN104453806A (zh) * 2014-10-30 2015-03-25 中国石油化工股份有限公司 一种注氮气解除砂岩凝析气藏水锁的方法

Also Published As

Publication number Publication date
EP2904197A2 (fr) 2015-08-12
DK178646B1 (en) 2016-10-10
WO2014056946A3 (fr) 2014-06-19
WO2014056946A2 (fr) 2014-04-17
DK201470330A (en) 2014-06-04

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