WO2013154945A1 - Optimisation de la récupération assistée du pétrole au moyen de traceurs de pétrole - Google Patents

Optimisation de la récupération assistée du pétrole au moyen de traceurs de pétrole Download PDF

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Publication number
WO2013154945A1
WO2013154945A1 PCT/US2013/035480 US2013035480W WO2013154945A1 WO 2013154945 A1 WO2013154945 A1 WO 2013154945A1 US 2013035480 W US2013035480 W US 2013035480W WO 2013154945 A1 WO2013154945 A1 WO 2013154945A1
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Prior art keywords
oil
tracer
injection
recovery process
formation
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PCT/US2013/035480
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English (en)
Inventor
Egil Sunde
Michael Raymond Pavia
Thomas Ishoey
Terje TORSIVK
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Glori Energy Inc.
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Publication date
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Publication of WO2013154945A1 publication Critical patent/WO2013154945A1/fr

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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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/11—Locating fluid leaks, intrusions or movements using tracers; using radioactivity

Definitions

  • Crude oil remains an important energy source. Crude oil producers typically produce oil by drilling wells into underground oil reservoirs in a formation. For some wells, the natural pressure of the oil is sufficient to bring the oil to the surface. This is known as primary recovery. Over time, as oil is recovered by primary recovery for these wells, the natural pressure drops and becomes insufficient to bring the oil to the surface. When this happens, a large amount of crude oil may still be left in the formation. Consequently, various secondary and tertiary recovery processes may be employed to recover more oil. Secondary and tertiary recovery processes may include: pumping, water injection, natural gas reinjection, air injection, carbon dioxide injection or injection of some other gas into the reservoir.
  • tracers are used to track fluid flow, for example, in a formation.
  • Water soluble, oil soluble and partitioning tracers are known to be used in tracking fluid flow.
  • An oil soluble tracer is soluble in oil but not in water.
  • a partitioning tracer has affinity for both oil and water.
  • partitioning tracers are soluble in both oil and water.
  • the partitioning tracer is in equilibrium between the oil phase and the water phase. The equilibrium constant of the partitioning tracer determines how much of the partitioning tracer is in the water phase as compared to the oil phase.
  • oil tracer as used herein, means oil soluble tracer or partitioning tracer.
  • the prevailing theory as to how the residual oil exists in a reservoir has influenced how tracers have been used to monitor fluid flow. For example, for partitioning tracers, though it is soluble in oil and water, its movement is usually determined by measuring tracer concentration in the water. Further, prevailing theory suggests that tracers will take a long time (e.g. months or years) to reach a production well after being injected into an injection well. Thus, current methods start monitoring the production wells long after the injection of the tracer and only after breakthrough of water tracer. Further, the current methods seek to identify a pulse (sharp increase and decline in concentration) of tracer in the production well.
  • embodiments of the invention include using an oil tracer to identify when oil is delivered to a production well consistent with the existence of strands between an injection well and a production well. When such a phenomenon is identified, oil recovery methods that are applied to the formation may be optimized so as to increase oil recovery.
  • the oil tracer can be an oil soluble tracer or a partial oil soluble tracer (partitioning tracer).
  • Embodiments of the invention include a method of recovering oil from a formation that comprises a production well and an injection well.
  • the formation having been water flooded to a residual oil saturation in all the formation or at least in part of the formation between the injection well and the production well, wherein water breakthrough has occurred in the production well.
  • the method includes injecting an oil tracer into the injection well in the formation and applying a tertiary oil recovery process for recovering the oil from the formation.
  • the method also includes monitoring oil recovered from the production well to detect oil tracer. The monitoring being conducted at least within a period that starts at the time the oil tracer is injected and ends 30 days after the oil tracer is injected or the period starts when the tertiary oil recovery process is started and ends 30 days after the oil recovery process is started.
  • FIGURE 1 shows a diagram of a system for implementing methods according to embodiments of the invention.
  • FIGURE 2 shows a flow chart illustrating steps according to embodiments of the invention.
  • FIGURES 3A - 3B shows a diagram of a system for implementing methods according to embodiments of the invention.
  • FIGURE 4 shows a flow chart illustrating steps according to embodiments of the invention.
  • FIGURE 5 shows a protocol set up for preparation of core experiments
  • FIGURES 6A - 6D shows results of production of water and oil tracer from core flooding experiments.
  • FIGURE 1 shows a diagram of a system for implementing methods according to embodiments of the invention.
  • System 10 includes an injection well 100 and a production well 101 in oil bearing formation 105.
  • Oil 102 resides in oil-bearing formation 105.
  • Oil-bearing formation 105 may be any type of geological formation and may be situated under overburden 104.
  • formation 105 is shown as being onshore in FIGURE 1, it should be appreciated that formation 105 may be located onshore or offshore.
  • oil 102 primarily exists as continuous phase strands 102-1 to 102-n within formation 105. The strands are of various lengths and may extend from injection well 100 to production well 101 as shown.
  • the strands are 3-dimensional in nature and may cross link to other strands throughout formation 105. See E. Sunde, B.-L. Lilleb0, T. Torsvik, SPE 154138, Towards a New Theory for Improved Oil Recovery from Sandstone Reservoirs (attached hereto as Appendix A), the disclosure of which is incorporated herein by reference in its entirety.
  • oil 102 is trapped within formation 105, not as distinct droplets, but as strands (e.g. strands 102- 1 to 102-n ) in portions of formation 105' s network of pores small enough to put up resistance to the surrounding 1 1 ure drop of surrounding water flow and keeps the oil from flowing to the production well 101.
  • Oil 102 is continuous and present throughout the pore networks between injection well 100 and production well 101. Between the pore networks, there may be other parts of formation 105 where water flow has almost completely cleared out the oil.
  • the oil will self organize according to the sum of pressures acting on it and the available pore network, thereby also redistributing some of its surrounding film of water. This and the fact that oil and water will seek the greatest possible separation to minimize friction, will leave the residual oil in continuous oil strands occupying pore spaces in all three dimensions. However, the general orientation of the oil strands will be parallel to the direction of flow due to the effect of shear forces.
  • injector well 100 is connected to producer well 101 by oil strands 102-1 - 102-n.
  • oil strands 102-1 - 102-n it will not be known if there are several or just a few oil strands providing the connection. That is, it will not be known whether there are sufficient strands between injection well 100 and producer well 101 to produce oil in sufficient quantities, when a recovery method such as water flooding is applied.
  • Identifying whether injector well 100 is connected to producer well 101 by oil strands 102-1 - 102-n may involve the use of an oil tracer. Once the connectivity by oil strands 102-1 - 102-n is identified between injector well 100 and producer well 101, the oil recovery process can be tailored towards increasing production from production well 101.
  • FIGURE 2 shows a flow chart illustrating steps according to embodiments of the invention.
  • Method 20 may include, at step 201, waterflooding formation 105 to a residual oil saturation. In some instances, this may be evident because water breakthrough has occurred at a production well. Formation 105 may have other producer wells in addition to producer well 101.
  • Step 202 involves injecting an oil tion well 100.
  • the oil tracer may include tritium labeled tetradecane (37 MBq, tetradecane [1,2-3H]4, pentacosane (C 25 H 52 ); hexacosane (C 26 H 54 ), heptacosane (C 27 H 56 ), octacosane(C 28 H 58 ), nonacosane(C 29 H 6 o), triacontane(C 3 oH 62 ), hentriacontane (C3IH64), dotriacontane(C32H66), tritriacontane (C33H68), tetratriacontane (C34H70) and the like and combinations thereof.
  • tritium labeled tetradecane 37 MBq, tetradecane [1,2-3H]4
  • pentacosane C 25 H 52
  • hexacosane C 26 H 54
  • a tertiary oil recovery process is applied to recover oil from formation 105.
  • injection of the oil tracer may be done at the same time, before or after step 203— tertiary oil recovery process— is started.
  • the tertiary oil recovery process may include microbial enhanced oil recovery, surfactant injection, polymer injection, water injection, natural gas reinjection, air injection, carbon dioxide injection, other gas injection, pressure pulses (water hammers) and combinations thereof.
  • Produced oil from production well 101 is monitored for the presence of the oil tracer at step 204. Consistent with the strand theory, it is assumed that once tertiary recovery step 203 has started, oil in the vicinity of injection well 100 and consequently the injected oil tracer may rapidly be produced at production well 101. Consequently, the monitoring is conducted at least within a period that starts at the time the oil tracer is injected and ends 30 days after the oil tracer is injected. Alternatively, the period starts when the tertiary oil recovery process is started and ends 30 days after the tertiary oil recovery process has started. Embodiments of the invention may use a period fewer than the 30 days described above.
  • the actual length of time will depend on the type of tertiary oil recovery process. For example, for gaseous oil recovery processes, it may be desirable that the period of monitoring starts at the time the oil tracer is injected and ends 7 days after the oil tracer is injected. Alternatively, the period may start when the tertiary oil recovery process is started and ends 7 days after the oil recovery process has started. The equivalent period for a surfactant flooding tertiary oil recovery process is about 30 days. It should be noted that although a period is identified herein during which monitoring should be conducted to identify the existence of oil strands between an injection well and a production well, in embodiments of the invention, monitoring can continue beyond this period to gather other information and to further optimize the tertiary oil recovery process.
  • the monitoring includes determining whether the oil tracer is
  • the monitoring process seeks to identify a consistent level of oil tracer in the oil produced as opposed to identifying a tracer pulse as is done for other tracer methods. See e.g. FIGURE 6A (showing a pulse of water tracer). As such, embodiments of the invention monitor the quantity of oil tracer in the oil produced from production well 101 as a function of time.
  • the tertiary oil recovery process may be modified to enhance the oil recovery process. Modifying the tertiary oil recovery process may involve changing any parameter in the tertiary oil recovery process that affects oil production. For example, changing the type and/or amount of surfactant injected during surfactant flooding, changing the type of gas used in gas injection, changing the amount and/or type of nutrients used in a microbial enhanced oil recovery process and the like.
  • FIGURES 3A to 3B show diagrams of a system for implementing methods according to embodiments of the invention.
  • System 30 shows oil formation 305, which has a plurality of injection wells and productions wells. Formation 305 has been water flooded to a residual oil saturation around the injection wells. In some instances, this may be evident because water breakthrough has occurred at a production well. Formation 305 is shown under overburden 304 and has drilled in it injection wells 300-A and 300-B and production wells 301-A to 301-C. In the configuration of system 30, it is desirable to know how oil production from production wells would be affected by treatment of the injection wells. To answer this question, one or more oil tracers may be used as described below.
  • FIGURE 4 shows a flow chart illustrating steps according to embodiments of the invention.
  • Method 40 may include, at step 401, water flooding formation 305 to a residual oil saturation.
  • Step 402 involves the application of a tertiary oil recovery process, examples of which are described above.
  • a first oil tracer may be injected into, for example, injection well 300-A.
  • Step 404 involves monitoring one or more of production wells 301-A - 301-C to see if oil produced from these one or more production wells contain the first oil tracer. As described above, the monitoring may be conducted at least within a period that starts at the time the oil tracer is injected and ends 7 or 30 days after the oil tracer is injected.
  • the period starts one month after the tertiary oil recovery process is started and ends 7 or 30 days after the oil recovery process has started.
  • the tertiary oil recovery process may then be modified at step 405 based on the detection of oil tracer in oil from production wells 301-A - 301-C during the monitoring period.
  • Modification in embodiments may include changing any parameter in a tertiary oil recovery process that affects oil production. The changes may be based on the amount of oil tracer detected over time during the monitoring period. For example, changing the type or amount, or both of surfactant injected during surfactant flooding, changing the amount of gas used in gas injection, changing the amount or type, or both of nutrients used in a microbial enhanced oil recovery process and the like.
  • a second tracer may be injected in injection well 300-A, at step 406.
  • the one or more production wells 301-A - 301-C are monitored for the second oil tracer (and if desired the first oil tracer). Monitoring may be done for periods as described in step 404. Based on the results of the monitoring steps 404 and 407, a determination may be made whether the modification at step 405 achieved positive results in terms of oil recovery from formation 305. Further, the production wells that provide the most improved results may be identified. At step 408, a determination may be made whether the tertiary oil recovery process has been improved to the extent where it is considered optimized.
  • Embodiments of the invention may also include the injection of a second, third and fourth oil tracer in, for example, injection well 300-B in a similar way as described above with injection well 300-A.
  • the tertiary oil recovery process is then applied via injection well 300-B. This may be done at the same time, before or after the injection of first oil tracer as described above for injection well 300-A.
  • each of production wells 301 -A to 300-C may be monitored for the first, second, third and fourth oil tracers. In this way, the interrelationships between the various wells can be determined.
  • embodiments of the invention include a method of optimizing recovery of oil from a formation that has a plurality of production wells and at least one injection well.
  • the method includes a process for identifying the existence of oil strands between the at least one injection well and at least one of the plurality of production wells.
  • the method also includes implementing a tertiary oil recovery process for recovering the oil from the formation based on the identification of oil strands and recovering oil from the formation as a result of the use of the implemented tertiary oil recovery process.
  • the use of the strand theory to optimize oil recovery as described herein gives unexpected results when compared with existing methods. For example, embodiments of the invention could result in an increase in production in the highest production well (the well having the largest pressure difference with the injection well) of a formation even if there are other production wells in between the highest production well and the injection well.
  • a water soluble tracer 35S labeled sodium sulphate (37MBq, 1.0 mCi Sodium [35S] sulphate dissolved in 10 ml brine), and an oil tracer; tritium labeled tetradecane (37 MBq, tetradecane [1,2-3H]4, lmCi dissolved in 40 ml crude oil) was used.
  • 35S labeled sodium sulphate 37MBq, 1.0 mCi Sodium [35S] sulphate dissolved in 10 ml brine
  • an oil tracer tritium labeled tetradecane (37 MBq, tetradecane [1,2-3H]4, lmCi dissolved in 40 ml crude oil) was used.
  • 50 ⁇ 1 oil sample was mixed with 1.8 ml heptane and 18 ml Ultima Gold LLT. Water samples were prepared by mixing ⁇ water with 3 ml Ultima Gold LLT. All samples were analyzed in
  • the cylindrical sandstone core was prepared to resemble a reservoir in the residual situation having water and oil in representative positions and locating the oil tracer near the inlet.
  • a volume of 35S-sulphate labelled brine was flooded through the core.
  • the first water tracer emerged after flooding 345 ml of water (equivalent to 0.88 pore volumes), the peak was obtained after flooding of 385 ml (equivalent to 0.99 pore volumes) and 99.5 % of the tracer was recovered after flooding 1.5 pore volumes (FIGURE 6A).
  • the core was filled with North Sea crude oil and 40 ml tritium labelled oil was injected.
  • the flow direction was reversed during water flooding to reach residual on, leaving the labelled oil at the inlet side at the start of the experiment (FIGURE 6B).
  • the oil and water production profiles indicate water wet sandstone core, as expected from Bentheimer cores with low clay mineral content.
  • the core was pressurized by pumping brine into the core with closed outlet valve to obtain 2 bars overpressure.
  • a pressure pulse was generated by opening the valve and thereby depressurizing the core. This resulted in immediate production (within 10 seconds) of 1.0 ml oil.
  • the oil was collected and the process of pressurizing and depressurizing was repeated twice, this time resulting in production of 0.2 and 0.1 ml oil.
  • the injection pump rate was set to 0.1 ml/min and produced oil and water was collected in 6 ml fractions, one fraction per hour. Tritiated tetradecane was detected in all oil samples.
  • the first oil fraction contained 233 Bq (total) of tritiated tetradecane tracer; the next two contained 40 and 30 Bq respectively.
  • the 4th oil fraction contained 4133 Bq and was produced after flooding with 31 ml water (FIGURE 6C).
  • FIGURE 6D oil production and the production of oil and water tracers are plotted together.
  • PV core pore volume, Swi; initial water saturation, Soi; initial
  • the oil strands can be produced sequentially, squeezed out by water flowing perpendicular to the oil strand. This would allow the oil located near the water injector to be produced together with the oil closest to the producer, in agreement with Jones findings.
  • the pressure pulse has been mathematically modeled and verified over one pore throat (Skaelaaen, I. 2010. Mathematical Modelling of Microbial Induced Processes in Oil Reservoirs. PhD thesis, University of Bergen, Bergen, Norway (2010)). The laboratory results are a scaling up from a pore length of approx. 20 microns to 0.76 meters, equivalent to approx. 4 * 104. A further scaling up to reservoir scale is only two more orders of magnitude.

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Abstract

Cette invention concerne un procédé d'optimisation de la récupération du pétrole à partir d'un gisement, comprenant les étapes consistant à : injecter un traceur de pétrole dans un puits d'injection dans le gisement et appliquer un procédé de récupération tertiaire de pétrole pour récupérer le pétrole du gisement. Un puits de production est surveillé pour détecter le traceur de pétrole dans le pétrole provenant des puits de production à des moments prédéterminés. Le procédé comprend en outre l'étape consistant à modifier le procédé de récupération tertiaire de pétrole sur la base de la détection du traceur de pétrole dans le pétrole provenant du puits de production.
PCT/US2013/035480 2012-04-13 2013-04-05 Optimisation de la récupération assistée du pétrole au moyen de traceurs de pétrole WO2013154945A1 (fr)

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US201261623946P 2012-04-13 2012-04-13
US61/623,946 2012-04-13
US13/827,639 2013-03-14
US13/827,639 US20140124196A1 (en) 2012-04-13 2013-03-14 Optimizing enhanced oil recovery by the use of oil tracers

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FR3036403B1 (fr) * 2015-05-21 2017-05-12 Ifp Energies Now Procede d'exploitation d'une formation souterraine par injection d'un fluide comprenant un additif marque par un nano-cristal semi-conducteur luminescent
US10502040B1 (en) 2018-06-15 2019-12-10 Baker Hughes, A Ge Company, Llc Upconverting nanoparticles as tracers for production and well monitoring
EP3680658B1 (fr) * 2019-01-11 2023-05-10 Grant Prideco, Inc. Système d'optimisation de production d'hydrocarbures
US11725139B2 (en) 2021-12-13 2023-08-15 Saudi Arabian Oil Company Manipulating hydrophilicity of conventional dye molecules for water tracer applications
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US12000278B2 (en) 2021-12-16 2024-06-04 Saudi Arabian Oil Company Determining oil and water production rates in multiple production zones from a single production well
US11859452B2 (en) 2022-04-08 2024-01-02 Baker Hughes Oilfield Operations Llc Wet connect system and method

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