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US20120241148A1 - Control of fluid flow during treatment of subterranean sites using well fluid injection - Google Patents

Control of fluid flow during treatment of subterranean sites using well fluid injection Download PDF

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Publication number
US20120241148A1
US20120241148A1 US13/241,361 US201113241361A US2012241148A1 US 20120241148 A1 US20120241148 A1 US 20120241148A1 US 201113241361 A US201113241361 A US 201113241361A US 2012241148 A1 US2012241148 A1 US 2012241148A1
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Prior art keywords
fluid
well
injection
subterranean
treatment fluid
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US13/241,361
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Albert W. Alsop
Scott Christopher Jackson
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EIDP Inc
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EI Du Pont de Nemours and Co
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Priority to US13/241,361 priority Critical patent/US20120241148A1/en
Assigned to E. I. DU PONT DE NEMOURS AND COMPANY reassignment E. I. DU PONT DE NEMOURS AND COMPANY ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: JACKSON, SCOTT CHRISTOPHER, ALSOP, ALBERT W.
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Abandoned 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
    • E21B43/20—Displacing by water
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
    • C09K8/582—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of bacteria

Definitions

  • This disclosure relates to the field of enhanced oil recovery or bioremediation. More specifically, it relates to controlling flow of treatment fluids and/or microorganisms into subterranean strata to enhance oil recovery or bioremediation.
  • Oil well sites are locations where wells have been drilled into a subterranean stratum, containing oil, with the intent to produce oil from that stratum.
  • An oil reservoir typically refers to a deposit of subterranean oil in a subterranean stratum.
  • Secondary oil recovery methods such as water flooding, that is injection of water through injection wells into the oil reservoir, have been used to force oil through the subterranean strata toward production wells and thus improve recovery of the crude oil (Hyne, N.
  • Production and injection wells are channels made by a well bore from the surface to the subterranean oil bearing strata with enough size to allow for pumping of fluids either from the surface and into the strata (injection wells) or from the strata to the surface (production wells).
  • Configuration of injection and associated production wells for enhanced oil recovery and bioremediation may take many forms, as is well known in the art (“Standard Handbook of Petroleum & Natural Gas Engineering”, 2nd Edition, Editors, William C. Lyons, Ph.D., P.E., Gary J. Plisga, B.S., Gulf Publishing, Elsevier, Burlington, Mass., USA).
  • Enhanced oil recovery (EOR) methods that utilize surfactant, polymer, alkali and microbial treatments have been known to improve water flooding performance of subterranean target sites.
  • Subterranean target sites refer to any subterranean site that is subject to treatment for EOR, microbial enhanced oil recovery (MEOR) or bioremediation.
  • MEOR microbial enhanced oil recovery
  • One problem commonly encountered with water flooding operations is that the heterogeneity of the subterranean strata can lead to reduced sweep efficiency of the water. Sweep efficiency is related to the fraction of the oil-bearing subterranean stratum that has seen water passing through it in order to move oil to the production wells.
  • Sweep efficiency can be reduced by several factors such as high permeable streaks, geometry of the wells and the strata, and viscous fingering.
  • water preferentially channels through the watered-out strata of the oil reservoir as it travels from the injection well to the production wells, thus bypassing the subterranean oil-bearing strata that are not watered-out.
  • the injection water has preferentially flowed through these strata and has removed most of the oil in that strata in contrast to adjacent strata that have seen little or no water.
  • U.S. Pat. No. 4,561,500 describes a method of reducing permeability of the underground formation by injecting microorganisms capable of producing insoluble exopolymers which accumulated in higher permeability zones.
  • WO2005005773 describes increasing sweep efficiency during oil recovery by injecting a consortium of microorganisms that produce surfactants.
  • U.S. Pat. No. 3,771,598 discloses injection of a mobilizing fluid into an injection well at a predetermined pressure and increasing the pressure in the formation by throttling outflow at the production well.
  • U.S. Pat. No. 4,184,549 discloses application of a low-viscosity fluid which forms a high-viscosity coarse emulsion with residual hydrocarbons thus reducing the permeability of the stratum to fluids.
  • the disclosed method is a method for treatment of a subterranean target site during oil recovery or bioremediation by controlling distribution of a well treatment fluid into said target site, the method comprising the steps of:
  • FIG. 1 depicts an inverted five spot injection well ( 1 ) and production wells ( 2 ) system.
  • fluid flow is controlled to ensure that well treatment fluids flow from the injection well to all of the surrounding production wells and are distributed throughout the subterranean strata so that adequate volumes of well treatment fluids flow to all areas of the subterranean strata without bypassing some areas and without excessive loss of fluids out of one or more production wells with short breakthrough time.
  • the volume of fluid that can be produced from a production well between the time a well treatment fluid is introduced at an injection well and the time that a significant amount of that well treatment fluid is seen at a production well is known as the “breakthrough volume” for that injection and production well pair.
  • Short breakthrough time refers to a breakthrough time that is shorter than the time required for the well treatment fluid to affect the desired changes in the subterranean target site and improve sweep efficiency. For example, it can be the time required for MEOR microorganisms to consume nutrients in nutritional chemical fluids used as treatment fluids (e.g., less than one day for low salt fluids, and less than 5 days for high salt fluids).
  • Low salt fluids are those well treatment fluids that contain less than 17 parts per thousand (ppt) of sodium chloride (hereafter referred to as “salt”) and high salt fluids are well treatment fluids that contain 50-60 ppt or higher levels of salt.
  • FIG. 1 One example of a suitable configuration of an injection well and associated production wells in an oil reservoir, which is a subterranean target site, is shown in FIG. 1 .
  • the single injection well ( 1 ) is in the center of the pattern and is labeled as “I”.
  • Other flow paths are possible depending on the nature of the rocks at the subterranean target site.
  • Any one of the flow paths illustrated in FIG. 1 can take significantly more of the introduced well treatment fluid and channel it to a particular production well and thus bypass parts of the subterranean target site.
  • This phenomenon can cause treatment of only some parts of the subterranean target site and loss of well treatment fluids out of one or more producing wells before the well treatment fluid can affect the desired changes necessary to improve sweep efficiency and to increase oil production from the subterranean target site.
  • the method disclosed herein allows for detection and elimination of this undesirable bypassing.
  • the fluid useful for water flooding according to the present method comprises water.
  • Water can be supplied from any suitable source, and can include, for example: sea water, brine, production water, water recovered from an underground aquifer, including those aquifers in contact with the oil, or surface water from a stream, river, pond or lake.
  • it may be necessary to remove particulate matter including dust, bits of rock or sand and corrosion by-products such as rust from the water prior to injection into the one or more well bores.
  • Methods to remove such particulate matter e.g., filtration, sedimentation and centrifugation, are well known in the art.
  • any treatment fluid such as chemical treatment fluids optionally including microorganisms
  • an analysis of the fluid flow pattern between an injection well and one or more production wells in the target subterranean site and the breakthrough volumes of the production wells is made.
  • Reservoir modeling, tracer testing, approximation methods, or any other method well known in the art can be used to estimate the breakthrough volume of any production well.
  • determination of distribution of the well treatment fluid allows identification of any particular flow path (e.g., as illustrated in FIG. 1 ) which takes significantly more of the well treatment fluid and channels it to a particular production well thus bypassing some parts of the subterranean target site.
  • Chemical or radioisotope tracer tests are common methods used in the oil industry to determine such bypassing and are suitable for use in the present invention.
  • Tracer chemicals used for this purpose include anions such as bromine, iodine, and nitrate or dyes such as the sodium salt of Fluorescein dye, commonly known as Uranine (CAS 518-47-8, Part number A833-500, Fisher Scientific, Pittsburgh, Pa.).
  • Radioisotope tracers such as hexacyanocobaltate, thiocyanate, tritiated water, halides or alcohols that contain radioisotope elements like Cobalt 60, Cobalt 58, Cobalt 57, Carbon 14, Tritium, Sulfur 35, Chlorine 36 or Iodine 125 are often used for tracer tests.
  • the flow through these production wells is controlled during treatment to allow distribution of the well treatment fluid throughout the subterranean target site and in particular to the areas that have not been watered-out.
  • the flow of treatment fluid By using the determined breakthrough times for several injection to production well pairings it is possible to sequentially restrict (or throttle) the flow of treatment fluid by partially closing the production valves or alternatively completely shutting off the flow from the production wells with short breakthrough times. This allows the treatment fluid to penetrate throughout the subterranean strata between the injection well and production wells with longer breakthrough times, and to provide for treatment across an entire subterranean target site.
  • the terms “restricting or throttling the flow” refers to reducing the flow from one or more production wells in order to allow the well treatment fluid to get distributed through the subterranean target site.
  • inoculum and inocula refer to microorganisms introduced into an injection well in a well treatment fluid.
  • “nutritional chemical fluids” refers to a fluid used for growth and colonization of either native microorganisms of the subterranean target site or exogenously added microorganisms for MEOR applications.
  • “Native microorganisms”, as used herein, refers to a variety of microorganisms that naturally exist in the subterranean target site.
  • “Exogenous microorganisms” or “exogenously added microorganisms” refers to microorganisms that are grown outside of the subterranean target site and then introduced into the site. This may include microorganisms that were isolated from the target or other subterranean site and then grown outside of the subterranean site before introduction.
  • the well treatment fluid can be a chemical treatment fluid and can comprise one or more polymeric fluids.
  • Polymeric fluids useful for the current method include, but are not limited to, water soluble polymers such as carboxymethylcellulose, hydroxyethylcellulose, carboxymethylhydroxyethylcellulose, guar gum, hydroxypropyl guar, carboxymethylhydroxypropyl guar, polyacrylamide, polyamines, xanthan, polysaccharides or polyvinylalcohol derivatives as those disclosed in commonly owned U.S. Pat. No. 7,6677,305, or polymers of 1,3 propanediol as disclosed in commonly owned and co-pending U.S. Patent Application 20090197779, which are herein incorporated by reference in their entireties.
  • the chemical treatment fluids may also comprise one or more surfactants.
  • the one or more surfactants useful for the current method include, but are not limited to: anionic sulfonates, nonionics (ethylene oxide derivatives), quaternary ammonium compounds, fluorosurfactants, amphoterics and glycol ethers or a mixture thereof.
  • the chemical treatment fluid may comprise at least one base having pKa above 10 wherein the resulting pH of the well treatment fluid is greater than 10.
  • Bases useful in the practice of the present invention include, but are not limited to: sodium silicate, sodium hydroxide or sodium carbonate or a mixture thereof.
  • the treatment can include any combination of polymer, surfactant and alkali treatment chemicals used at once or used in sequence.
  • the treatment fluid may also be a low salt fluid.
  • the treatment fluid can also be composed of a nutritional chemical fluid used by microorganisms to grow and to express a biological function resulting in improved oil recovery.
  • the nutritional chemical fluid may contain a suspension of microorganisms.
  • Microorganisms i.e., native microorganisms or exogenously added microorganisms
  • Many microorganisms live in various parts of subterranean strata and comprise the native microorganisms of such strata.
  • nutritional chemical fluids are introduced into the subterranean strata which encourage colonization and propagation of the native microorganisms in more permeable strata where they plug the pores of the permeable strata and thus block water flow through them.
  • Native microorganisms or exogenous microorganisms that grow in a subterranean site using nutritional chemical treatment fluids may also release oil from rock thereby reducing residual oil saturation.
  • microorganisms can be exogenously added to improve sweep efficiency and/or reduce residual oil saturation.
  • Microorganisms useful in the current method can comprise classes of facultative anaerobes, obligate anaerobes and denitrifiers.
  • microorganisms bacteria and fungi
  • bacteria and fungi Various species of microorganisms that can be used to improve sweep efficiency and enhance oil recovery include, but are not limited to, the genera: Pseudomonas, Bacillus, Actinomycetes, Acinetobacter, Arthrobacter, Schizomycetes, Corynebacteria, Achromobacteria, Arcobacter, Enterobacteria, Nocardia, Saccharomycetes, Schizosaccharomyces, Vibrio, Shewanella, Thauera, Petrotoga, Microbulbifer, Marinobacteria, Fusibacteria , and Rhodotorula .
  • the terms “genus” and “genera”, as used herein, refer to the category of microorganisms ranking below a “family” and above a “species” in the hierarchy of taxonomic classification of microorganisms.
  • the term “species” refers to a group of microorganisms that share a high degree of phenotypic, biochemical and genotypic similarities.
  • the inoculum can comprise only one particular species, or two or more species of the same genera, or a combination of different genera of microorganisms.
  • chemical well treatment fluid can comprise one or more nutritional chemical fluids.
  • Nutritional chemical fluids useful in the present invention include those containing at least one of the following elements: C, H, O, P, N, S, Mg, Fe, or Ca.
  • inorganic compounds that may be used include PO 4 2 ⁇ , NH 4 + , NO 2 ⁇ , NO 3 ⁇ , and SO 4 2 ⁇ amongst others.
  • Techniques and various suitable nutrient-containing fluids for growth and maintenance of facultative and strict anaerobic microorganisms are well known in the art.
  • Growth substrates can include sugars, organic acids, alcohols, proteins, polysaccharides, fats, hydrocarbons or other organic materials known in the art of microbiology to be subject to microbial decomposition.
  • Major nutrients containing nitrogen and phosphorus can include NaNO 3 , KNO 3 , NH 4 NO 3 , Na 2 HPO 4 , K 2 HPO 4 , NH 4 Cl); vitamins (non-limiting examples can include folic acid, ascorbic acid, and riboflavin); trace elements (non-limiting examples can include B, Zn, Cu, Co, Mg, Mn, Fe, Mo, W, Ni, and Se); buffers for environmental controls; catalysts, including enzymes; and both natural and artificial electron acceptors.
  • h means hour(s); “L” means litre; “° C.” means degrees Celsius; “mg” means milligram(s); “mm” means millimeter; “kg” means kilogram(s); “ppt” means part per thousand; “mM” means millimolar; “%” means percent; “min” means minute(s); “mL/min means milliliter per minute; “D” means day(s); “ ⁇ g/L” means microgram per liter; “nM” means nanomolar; “ ⁇ M” means micromolar.
  • the breakthrough time for each production well is determined using a tracer chemical such as a sodium salt of Fluorescein dye, commonly known as Uranine (CAS 518-47-8, Part number A833-500, Fisher Scientific, 2000 Park Lane Drive, Pittsburgh, Pa. 15275).
  • a tracer chemical such as a sodium salt of Fluorescein dye, commonly known as Uranine (CAS 518-47-8, Part number A833-500, Fisher Scientific, 2000 Park Lane Drive, Pittsburgh, Pa. 15275).
  • Uranine (2.7 kilogram, kg) is added to a tank containing 9,000 L of water.
  • the normal flow of injection water to the injection well to be tested is shut off.
  • the Uranine treated water is injected over a 7.2 hours (h) period into the injection well at a rate of injection equal to 1,250 L/h which is the normal injection flow rate.
  • the normal injection flow of water is restored at the normal injection rate of 30,000 L/D.
  • samples are taken from the associated production wells at various time intervals for example, 6, 12, 18, 24, 36, 48 h following initial tracer fluid injection and it is then followed by taking samples at longer intervals. For examples samples are taken at daily intervals.
  • the samples are allowed to settle and separate into water and oil layers.
  • the water layer is removed and placed in a small clear glass sample vial and its color is visually compared against similar tubes of injection water prepared with known concentrations of Uranine.
  • concentrations of Uranine in water can be visually estimated.
  • the dye concentration in the water samples can be estimated.
  • the injection and production wells of a subterranean site are arranged in an inverted five spot pattern as shown in FIG. 1 .
  • production well P 2 has the shortest breakthrough time followed by production well P 4 with the second shortest breakthrough time.
  • a microbial inoculum suspension is prepared by making in a 6,000 L tank a nutritional chemical fluid appropriate for the particular microorganism used. A microbial inoculum is then added to the nutritional chemical fluid to produce a suspension at the desired concentration of microbes and nutrients.
  • total well treatment period does not exceed the breakthrough times between any well pairing.

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CN104312562A (zh) * 2014-11-10 2015-01-28 天津亿利科能源科技发展股份有限公司 一种用于微生物采油过程中的营养凝胶缓释方法
US20150204176A1 (en) * 2014-01-21 2015-07-23 Montana Emergent Technologies Inc. Methods for Increased Hydrocarbon Recovery Through Mineralization Sealing of Hydraulically Fractured Rock Followed by Refracturing
US10030514B2 (en) * 2013-01-03 2018-07-24 Titan Oil Recovery, Inc. Method of monitoring the flow of natural or injected water during oil field recovery processes using an organic tracer
US11103819B2 (en) * 2015-06-29 2021-08-31 SegreTECH Inc. Method and apparatus for removal of sand from gas
JP2022151501A (ja) * 2021-03-26 2022-10-07 三菱マテリアルテクノ株式会社 土壌浄化剤及び土壌浄化方法

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RU2525537C1 (ru) * 2013-03-28 2014-08-20 Открытое акционерное общество "Нефтяная компания "Роснефть" Полимерная композиция для высокоминерализованных утяжеленных буровых растворов на водной основе
EP4575178A3 (en) * 2014-07-03 2025-08-06 Titan Oil Recovery, Inc. Method of monitoring the flow of natural or injected water during oil field recovery processes using an organic tracer
CN104808258B (zh) * 2015-04-03 2017-05-10 徐州工程学院 利用糖作为示踪剂测定岩溶地下水运移路径的方法
CN107558973A (zh) * 2016-07-01 2018-01-09 中国石油化工股份有限公司 一种通过油井实施微生物驱油的方法
GB2582841B (en) * 2019-08-19 2021-09-08 Clear Solutions Holdings Ltd Automated fluid system
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CN103154430A (zh) 2013-06-12
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