NO172757B - TENSID MIXTURE AND PROCEDURE FOR TERTIAS OIL TRANSPORT - Google Patents
TENSID MIXTURE AND PROCEDURE FOR TERTIAS OIL TRANSPORT Download PDFInfo
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- NO172757B NO172757B NO852456A NO852456A NO172757B NO 172757 B NO172757 B NO 172757B NO 852456 A NO852456 A NO 852456A NO 852456 A NO852456 A NO 852456A NO 172757 B NO172757 B NO 172757B
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- 239000000203 mixture Substances 0.000 title claims description 17
- 238000000034 method Methods 0.000 title claims description 13
- 239000004094 surface-active agent Substances 0.000 claims description 27
- 239000008398 formation water Substances 0.000 claims description 10
- 125000000217 alkyl group Chemical group 0.000 claims description 9
- 239000010779 crude oil Substances 0.000 claims description 7
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims description 6
- 125000004432 carbon atom Chemical group C* 0.000 claims description 6
- 229910052739 hydrogen Inorganic materials 0.000 claims description 6
- 239000001257 hydrogen Substances 0.000 claims description 6
- 125000002496 methyl group Chemical group [H]C([H])([H])* 0.000 claims description 6
- 239000003208 petroleum Substances 0.000 claims description 5
- 239000003945 anionic surfactant Substances 0.000 claims description 4
- 229920000642 polymer Polymers 0.000 claims description 4
- 239000007864 aqueous solution Substances 0.000 claims description 3
- 239000002736 nonionic surfactant Substances 0.000 claims description 3
- 230000032258 transport Effects 0.000 claims description 3
- 230000009049 secondary transport Effects 0.000 claims description 2
- 230000009046 primary transport Effects 0.000 claims 1
- 239000003921 oil Substances 0.000 description 21
- 150000003839 salts Chemical class 0.000 description 10
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 description 9
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 8
- 238000005188 flotation Methods 0.000 description 6
- 125000001273 sulfonato group Chemical group [O-]S(*)(=O)=O 0.000 description 6
- 238000012360 testing method Methods 0.000 description 6
- 230000015572 biosynthetic process Effects 0.000 description 5
- 238000005755 formation reaction Methods 0.000 description 5
- 239000011148 porous material Substances 0.000 description 5
- 239000000243 solution Substances 0.000 description 5
- 229920000663 Hydroxyethyl cellulose Polymers 0.000 description 4
- RTZKZFJDLAIYFH-UHFFFAOYSA-N ether Substances CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 description 4
- 238000000605 extraction Methods 0.000 description 4
- 235000019447 hydroxyethyl cellulose Nutrition 0.000 description 4
- 239000011435 rock Substances 0.000 description 4
- 239000004576 sand Substances 0.000 description 4
- 239000004354 Hydroxyethyl cellulose Substances 0.000 description 3
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 3
- 229920001222 biopolymer Polymers 0.000 description 3
- -1 ether sulfonates Chemical class 0.000 description 3
- 238000011084 recovery Methods 0.000 description 3
- IAYPIBMASNFSPL-UHFFFAOYSA-N Ethylene oxide Chemical compound C1CO1 IAYPIBMASNFSPL-UHFFFAOYSA-N 0.000 description 2
- 241000237858 Gastropoda Species 0.000 description 2
- TWRXJAOTZQYOKJ-UHFFFAOYSA-L Magnesium chloride Chemical compound [Mg+2].[Cl-].[Cl-] TWRXJAOTZQYOKJ-UHFFFAOYSA-L 0.000 description 2
- 125000002877 alkyl aryl group Chemical group 0.000 description 2
- 125000000129 anionic group Chemical group 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 229920002678 cellulose Polymers 0.000 description 2
- 239000001913 cellulose Substances 0.000 description 2
- 150000001875 compounds Chemical class 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- CXHHBNMLPJOKQD-UHFFFAOYSA-N methyl hydrogen carbonate Chemical compound COC(O)=O CXHHBNMLPJOKQD-UHFFFAOYSA-N 0.000 description 2
- 239000004530 micro-emulsion Substances 0.000 description 2
- 229920000151 polyglycol Polymers 0.000 description 2
- 239000010695 polyglycol Substances 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- 230000035945 sensitivity Effects 0.000 description 2
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 description 1
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- RZXLPPRPEOUENN-UHFFFAOYSA-N Chlorfenson Chemical compound C1=CC(Cl)=CC=C1OS(=O)(=O)C1=CC=C(Cl)C=C1 RZXLPPRPEOUENN-UHFFFAOYSA-N 0.000 description 1
- 206010014415 Electrolyte depletion Diseases 0.000 description 1
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 230000002378 acidificating effect Effects 0.000 description 1
- 150000001298 alcohols Chemical class 0.000 description 1
- 229940045714 alkyl sulfonate alkylating agent Drugs 0.000 description 1
- 150000008052 alkyl sulfonates Chemical class 0.000 description 1
- 239000001110 calcium chloride Substances 0.000 description 1
- 229910001628 calcium chloride Inorganic materials 0.000 description 1
- 235000011148 calcium chloride Nutrition 0.000 description 1
- 238000006555 catalytic reaction Methods 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 229920001577 copolymer Polymers 0.000 description 1
- 239000003599 detergent Substances 0.000 description 1
- MTHSVFCYNBDYFN-UHFFFAOYSA-N diethylene glycol Chemical compound OCCOCCO MTHSVFCYNBDYFN-UHFFFAOYSA-N 0.000 description 1
- 150000004676 glycans Chemical class 0.000 description 1
- 230000007062 hydrolysis Effects 0.000 description 1
- 238000006460 hydrolysis reaction Methods 0.000 description 1
- 230000015784 hyperosmotic salinity response Effects 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 150000002500 ions Chemical class 0.000 description 1
- 229910001629 magnesium chloride Inorganic materials 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000012856 packing Methods 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 229920002401 polyacrylamide Polymers 0.000 description 1
- 229920002959 polymer blend Polymers 0.000 description 1
- 229920001282 polysaccharide Polymers 0.000 description 1
- 239000005017 polysaccharide Substances 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 239000000523 sample Substances 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- QAOWNCQODCNURD-UHFFFAOYSA-L sulfate group Chemical group S(=O)(=O)([O-])[O-] QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 1
- BDHFUVZGWQCTTF-UHFFFAOYSA-N sulfonic acid Chemical compound OS(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-N 0.000 description 1
- 229920001059 synthetic polymer Polymers 0.000 description 1
- 229920003002 synthetic resin Polymers 0.000 description 1
- 239000000057 synthetic resin Substances 0.000 description 1
- 238000010998 test method Methods 0.000 description 1
- 230000008719 thickening Effects 0.000 description 1
- 239000003643 water by type Substances 0.000 description 1
- 229920001285 xanthan gum Polymers 0.000 description 1
Classifications
-
- 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
- C09K8/584—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 specific surfactants
Description
Foreliggende oppfinnelse vedrører en fremgangsmåte ved tertiærtransport av jordolje, samt tensidblandinger for bruk deri. The present invention relates to a method for tertiary transport of petroleum, as well as surfactant mixtures for use therein.
Det er kjent at ved utvinning av olje fra oljeførende reservoarer kan bare en liten del av den opprinnelig tilstede-værende olje transporteres ved primære og sekundære utvinn-ingsprosesser. It is known that when extracting oil from oil-bearing reservoirs, only a small part of the originally present oil can be transported by primary and secondary extraction processes.
En økning av oljeutbyttet oppnås ved tertiære prosesser. Dermed menes en fremgangsmåte ved hvilken enten oljens visko-sitet nedsettes eller viskositeten til det etterflotterende vannet økes, eller det dreier seg om tensidfIotasjonsprosesser som i første linje bygger på en sterk senkning av grenseflate-spenningen mellom olje og reservoarvann henholdsvis forma-sj onsbergart. An increase in the oil yield is achieved by tertiary processes. By this is meant a method by which either the oil's viscosity is reduced or the viscosity of the post-flotation water is increased, or it is a matter of tension flotation processes which are primarily based on a strong lowering of the interfacial tension between oil and reservoir water or formation rock.
En oversikt over de tidligere anvendte viktigste grense-flateaktive forbindelser finnes i litteraturkilden: "Tenside fiir die Tertiårforderung von Erdol im hochsalinaren System", Tenside Detergents 17 (1980), 2.K. Oppenlånder, M.K: Akstinat, M.I. Murtarda. An overview of the previously used most important surface-active compounds can be found in the literature source: "Tenside fiir die Tertiårforderung von Erdol im hochsalinaren System", Tenside Detergents 17 (1980), 2.K. Oppenlånder, M.K: Akstinat, M.I. Murtarda.
Blant de der omtalte tensider er spesielt sulfonatene viktige for foreliggende formål. Ifølge europeisk patent-ansøkning 0047369 beskrives virksomme tensider på karboksy-metyleterbasis. En spesielt sterk absorbsjon til bergarten i motsetning til sulfonatene synes imidlertid å vanskeliggjøre en anvendelse. Dertil bevirker karboksymetyleter nær inver-sjonstemperaturpunktet, ved hvilket tensidet anvendes og er virksomt, en sterk fortykning av oljen, og dette fører, selv ved relativt sterkt gjennomtrengelige kunstige formasjoner, Among the surfactants mentioned there, the sulphonates are especially important for the present purpose. According to European patent application 0047369, active surfactants based on carboxy methyl ether are described. However, a particularly strong absorption to the rock in contrast to the sulphonates seems to make application difficult. In addition, carboxymethyl ether near the inversion temperature point, at which the surfactant is used and is effective, causes a strong thickening of the oil, and this leads, even with relatively highly permeable artificial formations,
til trykkforskjeller på mer enn 40 bar/m og ved overføring i felten til trykk langt over det petrostatiske trykk (H. to pressure differences of more than 40 bar/m and when transferred in the field to pressures well above the petrostatic pressure (H.
Murtarda, M. Kurkowsky, Erdol Erdgas Zeitschrift 93_; 303 Murtarda, M. Kurkowsky, Erdol Erdga's Zeitschrift 93_; 303
(1977) . (1977).
Som oljemobiliserende tensider nevnes derfor fremfor alt organiske sulfonater så som alkyl, alkylaryl eller petroleum-sulfonater. Disse har en meget lav toleransegrense overfor saltinnholdet til reservoarvannet. Saltkonsentrasjoner på Oil-mobilizing surfactants are therefore above all organic sulphonates such as alkyl, alkylaryl or petroleum sulphonates. These have a very low tolerance limit to the salt content of the reservoir water. Salt concentrations on
0,1% med spesiell ømfintlighet overfor toverdige ioner anses 0.1% with special sensitivity to divalent ions is considered
her allerede som problematiske. Da imidlertid mange reservoarvann har saltinnhold opptil 25%, så som f.eks. i Nord-Tyskland, kan sulfonatene ikke utnyttes alene. Ifølge kanadisk patent 1.02 6.666 og US patent 3.811.505, har man derfor forsøkt å redusere denne elektrolyttømfintligheten ved tilsetning av ko-overflateaktive midler så som alkoholer, hvilket imidlertid nedsetter virkningsgraden. here already as problematic. Since, however, many reservoir waters have a salt content of up to 25%, such as e.g. in northern Germany, the sulphonates cannot be used alone. According to Canadian patent 1,02 6,666 and US patent 3,811,505, an attempt has therefore been made to reduce this electrolyte depletion by adding co-surfactant agents such as alcohols, which however reduces the degree of effectiveness.
Til slutt var anvendelsen av alkylarylpolyglykoleter-sulfonater alene kjent for seknudærtransporten. I motsetning til alkylsulfonatene, viste alkyl- henholdsivs alkylarylpoly-glykoletersulfonatené en god toleranse med høye saltinnohld, men sulfatgruppens hydrolyseømfintlighet i sure medier ved høyere temperatur som forekommer i de fleste reservoarer, begrenser imidlertid anvendeligheten sterkt. Finally, the use of alkylaryl polyglycol ether sulfonates was known only for secondary transport. In contrast to the alkyl sulfonates, the alkyl or alkylarylpolyglycol ether sulfonates showed a good tolerance with high salt contents, but the sensitivity of the sulfate group to hydrolysis in acidic media at the higher temperature that occurs in most reservoirs, however, severely limits their applicability.
Derfor kunne de tidligere kjente tensider eller tensidblandinger ikke virke tilfredsstillende med hensyn til olje-utvinnignsvirkning, bestandighet og toleranse ved høye saltinnhold. Therefore, the previously known surfactants or surfactant mixtures could not work satisfactorily with regard to oil extraction effect, durability and tolerance at high salt contents.
Følgelig forelå opgaven å frembringe en fremgangsmåte og en tensidblanding som tillater en høy oljeutvinning fra reservoarene ved god salt-toleranse. Consequently, the task was to produce a method and a surfactant mixture that allows a high oil recovery from the reservoirs with good salt tolerance.
Man har nå overraskende funnet at dette kan oppnås med tensidblandinger som inneholder som vesentlige bestanddeler It has now surprisingly been found that this can be achieved with surfactant mixtures containing as essential components
a) et anionaktivt tensid med formel a) an anionic surfactant with formula
hvori in which
R<1> er en rettkjedet eller forgrenet alkylgruppe med 8 til R<1> is a straight-chain or branched alkyl group with 8 more
15, fortrinnsvis 8 til 12 karbonatomer, 15, preferably 8 to 12 carbon atoms,
R<2> hydrogen eller metyl, og R<2> hydrogen or methyl, and
x tallene 1 til 2, fortrinnsvis 1, x the numbers 1 to 2, preferably 1,
b) et ikkeionisk tensid med formelen b) a nonionic surfactant with the formula
hvori in which
R<1> betyr en rettkjedet eller forgrenet alkylgruppe R<1> means a straight-chain or branched alkyl group
med 8 til 15 karbonatomer, with 8 to 15 carbon atoms,
R<2> betyr hydrogen eller metyl, R<2> means hydrogen or methyl,
y tallene 3 til 16, y the numbers 3 to 16,
og hvorunder vektforholdet a:b er 4:1 til 1:10. and wherein the weight ratio a:b is 4:1 to 1:10.
Med vandige løsninger av tensidblandingen ifølge oppfinnelsen kan man nemlig oppnå høye oljeutvinningsgrader opptil 97%. With aqueous solutions of the surfactant mixture according to the invention, high oil recovery rates of up to 97% can be achieved.
Glykoletersulfonatet som bare er delvis løselig i salt-holdig løsning, bringes i løsning med alkylpolyglykoleteren, og blandingen er også fremragende stabil ved høye temperaturer i formasjonsvann med høyt saltinnhold. Det nye tensidsystem har med 8 x 10~<3> mN/m en meget lav grenseflatespenning overfor råolje, og dette er en viktig forutsetning for en god oljeutvinning (M. Burkowsky, C. Marx; Erdol - Erdgaszeitschrift, 95. Jg., Januar 1979). Samtidig viser imidlertid systemet en viss ønsket labilitet overfor hydrokarbonet. Ved tilsetning av råolje dannes en mikroemulsjon som består av tensid, hydro-karboner og saltvann. Etter vanlig oppfatning er dannenlsen av en mikroemulsjon en forutsetning for en god oljemobilisering. Denne egenskap prøves i "faseforsøk", hvorunder samme mengde råolje og tensidblanding rystes og så lagres ved høyere temperatur. Dannelsen av en svart opaleszent, lettbevegelig mellomfase er en forutsetning for et virksomt produkt, spesielt danner blandingen ifølge oppfinnelsen av dodecylfenylmonoglykoletersulfonat/monylfenol-oktaetoksylat (25 ml, 6% i formasjonsvann) med råolje (25 ml) ved 40°C 7 ml av en slik mellomfase. The glycol ether sulfonate, which is only partially soluble in saline solution, is brought into solution with the alkyl polyglycol ether, and the mixture is also remarkably stable at high temperatures in formation water with a high salt content. With 8 x 10~<3> mN/m, the new surfactant system has a very low interfacial tension in relation to crude oil, and this is an important prerequisite for good oil recovery (M. Burkowsky, C. Marx; Erdol - Erdgaszeitschrift, 95. Jg., January 1979). At the same time, however, the system shows a certain desired lability towards the hydrocarbon. When crude oil is added, a microemulsion is formed which consists of surfactant, hydrocarbons and salt water. According to common opinion, the formation of a microemulsion is a prerequisite for good oil mobilization. This property is tested in "phase tests", during which the same amount of crude oil and surfactant mixture is shaken and then stored at a higher temperature. The formation of a black opalescent, easily mobile intermediate phase is a prerequisite for an active product, in particular the mixture according to the invention of dodecylphenyl monoglycol ether sulfonate/monylphenol octaethoxylate (25 ml, 6% in formation water) with crude oil (25 ml) at 40°C forms 7 ml of a such intermediate phase.
Foreliggende oppfinnelse gir en forbedret fremgangsmåte for utvinning av olje. The present invention provides an improved method for extracting oil.
Ifølge denne fremgangsmåte blir 1 til 20 vektprosentige løsninger av en forannevnt tensidblanding presset inn i et underjordisk reservoar hvis formasjonsvann har et høyt totalt saltinnhold med etterfølgende innpressing av formasjonsvann som eventuelt er fortykket med biopolymerer så som xantaner eller cellulosederivater så som hydroksyetylcellulose. According to this method, 1 to 20 percent by weight solutions of a aforementioned surfactant mixture are pressed into an underground reservoir whose formation water has a high total salt content with subsequent injection of formation water which is possibly thickened with biopolymers such as xanthans or cellulose derivatives such as hydroxyethyl cellulose.
Den anioniske/ikkeanioniske tensidblanding ifølge oppfinnelsen har den fordel i forhold til forbindelsene med 'formel The anionic/non-anionic surfactant mixture according to the invention has the advantage compared to the compounds with 'formula
som er beskrevet i kanadisk patentskrift nr. 1.086.046 og forbindelse med formel which is described in Canadian Patent No. 1,086,046 and connection with formula
eller or
som er beskrevet i DT nr. 2.558.548, hvori de anioniske og de ikke-ioniske bestanddeler er forenet i samme molekyl, ved siden av den genenrelt forbedrede oljeutvinningsvirkning, at den bare ved forandring av andelen og arten av den ikke-ioniske komponent kan tilpasses de ofte varierende reservoarforhold (temperatur, trykk, saltinnhold i reservoarvannet, råolje-sammensetning, bergartformasjonenes porøsitet og kapasitet o.s.v.). Det er en spesiell fordel ved oppfinnelsen at like-vekten er enkel å innstille med hensyn til hydrofobi og hydrofili av bestanddelene. which is described in DT no. 2,558,548, in which the anionic and the non-ionic components are united in the same molecule, next to the generally improved oil extraction effect, that only by changing the proportion and nature of the non-ionic component can adapted to the often varying reservoir conditions (temperature, pressure, salt content of the reservoir water, crude oil composition, porosity and capacity of the rock formations, etc.). It is a particular advantage of the invention that the equilibrium is easy to set with regard to the hydrophobicity and hydrophilicity of the components.
I deltaj utfører man tensidfIotasjonen analogt det som er beskrevet i DE 25 58 548, som det hermed henvises til. In deltaj, the tensiftIotation is carried out analogously to what is described in DE 25 58 548, to which reference is hereby made.
Virkningsgraden til de nye tensidblandinger anskuelig-gjøres i de følgende eksempler. Man går frem som følger: Etoksylatene som skal anvendes fremstilles etter kjente metoder ved omsetning av alkohol eller alkylfenolene med den ønskede mengde etylenoksyd og alkalisk katalyse (0.5% KOH) ved 120°C i autoklaver. For å fremstille sulfonatene, omsettes 1 mol alkylfenol etter kjente metoder med 1 mol C1S03H eller SO3 ved 20 til 50°C. Sulfonsyren som dannes nøytraliseres med 50%ig NaOH. Etter tilsetning av 5 mol-% NaOH, omsettes den vandige løsning ved 120°C i autoklaver med 1 til 2 mol etylenoksyd. Overskuddet av NaOH nøytraliseres etter reaksjon med HC1. The effectiveness of the new surfactant mixtures can be seen in the following examples. The procedure is as follows: The ethoxylates to be used are prepared according to known methods by reacting alcohol or the alkylphenols with the desired amount of ethylene oxide and alkaline catalysis (0.5% KOH) at 120°C in an autoclave. To prepare the sulfonates, 1 mol of alkylphenol is reacted according to known methods with 1 mol of C1SO3H or SO3 at 20 to 50°C. The sulphonic acid that is formed is neutralized with 50% NaOH. After addition of 5 mol% NaOH, the aqueous solution is reacted at 120°C in an autoclave with 1 to 2 mol of ethylene oxide. The excess of NaOH is neutralized after reaction with HC1.
Flotasjonen med tensidløsningen som skal anvendes ifølge oppfinnelsen, kan presses inn enten kontinuerlig eller i form av slugs, dvs. et snevert begrenset volum på 0,02 til 0,5 ganger porevolumet til reservoarbergarten, borkjernen eller sandpakningen. Størrelsen av tensidslugs avhenger av tensid-konsenterasjonen og økonomien. Konsentrasjonen er som regel 5% med en bruksmengde på 0,1 x porevolumet. Som lineær laboratoriemodell for reservoaret anvendes for utprøving borkjerner (100 - 300 mm lange, 20 - 30 mm tverrsnitt) av Bendheimer sandstein, som er innstøpt i kunstharpiks eller bly. Samtidig utføres utprøvningene på sandpakninger (korn-størrelse 0,03 - 0,15 mm, porøsitet: 40%, permeabilitet: 3900 mD, restvann: 15%) i termostabiliserte trykkrør på 25 eller 100 cm lengde og 20 mm tverrsnitt. The flotation with the surfactant solution to be used according to the invention can be pressed in either continuously or in the form of slugs, i.e. a narrowly limited volume of 0.02 to 0.5 times the pore volume of the reservoir rock, drill core or sand packing. The size of surfactant slugs depends on the surfactant concentration and economics. The concentration is usually 5% with a usage quantity of 0.1 x the pore volume. As a linear laboratory model for the reservoir, drill cores (100 - 300 mm long, 20 - 30 mm cross section) of Bendheimer sandstone, embedded in synthetic resin or lead, are used for testing. At the same time, the tests are carried out on sand packs (grain size 0.03 - 0.15 mm, porosity: 40%, permeability: 3900 mD, residual water: 15%) in thermostabilized pressure pipes of 25 or 100 cm length and 20 mm cross section.
Prøvematerialet flotteres fortrinnsvis med syntetisk formasjonsvann med følgende sammensetning: 8,4 vektprosent NaCl, 2,9 vektprosent CaCl2, 0,9 vektprosent MgCl2, pH = 6. Porerommet til borkjernen eller sandhaugen, fremstilt med et rysteforsøk, utfylles med formasjonsvannet som så med råolje igjen fortrenges opptil 15%. Slikt oljemettet materiale flotteres da med formasjonsvann ved forsøkstemperaturen på 40°C så lenge med hastighet på l,5m/d, at en utvanningsgrad på 99-100% oppnås etter gjennomløp av 2 ganger porevolumet, hvilket tilsvarer den sekundære vann-fIotasjon. Det oppnås som oljeutvinning ca. 7 0%. Den gjenværende olje står til rådighet for den etterfølgende tensidfIotasjon og anslås som restoljemetning Sq^- 100%. Etter tensidslagget injiserer man hensiktsmessig både for mobilitetskontroll og for beskyttelse av tensid-løsningen, en polymerslug før inntrengende formasjonsvann. I denne hensikt oppløses en polymer eller polymerblanding i en slik konsentrasjon i formasjonsvannet at viskositeten er minst så høy som oljens. Som polymerer kommer her biopolymerer i betraktning, f.eks. det som selges av Pfitzer under handels-navnene "Flocon", Biopolymer 4800, polysakkarider eller cellulose-derivater så som hydroksyetylcellulose, f.eks. "Natrosol" HH250 fra Hercules Powder, eller syntetiske polymerer på basis av kopolymerer, polyakrylamider og - akrylater. The sample material is preferably floated with synthetic formation water with the following composition: 8.4% by weight NaCl, 2.9% by weight CaCl2, 0.9% by weight MgCl2, pH = 6. The pore space of the drill core or sand pile, prepared with a shaking test, is filled with the formation water as if with crude oil again up to 15% is displaced. Such oil-saturated material is then floated with formation water at the test temperature of 40°C for so long at a speed of 1.5m/d, that a dewatering degree of 99-100% is achieved after passage of 2 times the pore volume, which corresponds to secondary water flotation. It is achieved as oil extraction approx. 70%. The remaining oil is available for the subsequent tensifdIotation and is estimated as residual oil saturation Sq^- 100%. After the surfactant layer, a polymer slug is suitably injected both for mobility control and for protection of the surfactant solution before penetrating formation water. For this purpose, a polymer or polymer mixture is dissolved in such a concentration in the formation water that the viscosity is at least as high as that of the oil. As polymers, biopolymers come into consideration here, e.g. that sold by Pfitzer under the trade names "Flocon", Biopolymer 4800, polysaccharides or cellulose derivatives such as hydroxyethyl cellulose, e.g. "Natrosol" HH250 from Hercules Powder, or synthetic polymers based on copolymers, polyacrylamides and - acrylates.
Prøver fra sandpakninger som bekreftes på kortborkjerner: Til CA 1.086.046 og DT 2.558.548 Samples from sand packs confirmed on short drill cores: To CA 1.086.046 and DT 2.558.548
Prøvemetode: Slug-fIotasjon med 0,1 porevolumer, 5%ig tensidløsning, slik at 2,5% tensid i forhold til oljen som skal beveges står til rådighet, etterflottert med 0,4% hydroksyetylcellulose i ca. 12% saltvann. Test method: Slug flotation with 0.1 pore volumes, 5% surfactant solution, so that 2.5% surfactant in relation to the oil to be moved is available, post-flotation with 0.4% hydroxyethyl cellulose for approx. 12% salt water.
SQR = restoljernetning i prosent av oljemengden som står til rådighet for prøving. SQR = residual oil reduction as a percentage of the amount of oil available for testing.
Claims (3)
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
DE19843422613 DE3422613A1 (en) | 1984-06-19 | 1984-06-19 | SURFACTANT MIXTURE AND THEIR USE FOR TERTIAL OIL DELIVERY |
Publications (3)
Publication Number | Publication Date |
---|---|
NO852456L NO852456L (en) | 1985-12-20 |
NO172757B true NO172757B (en) | 1993-05-24 |
NO172757C NO172757C (en) | 1993-09-01 |
Family
ID=6238644
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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NO852456A NO172757C (en) | 1984-06-19 | 1985-06-18 | TENSID MIXTURE AND PROCEDURE FOR TERTIAS OIL TRANSPORT |
Country Status (3)
Country | Link |
---|---|
EP (1) | EP0167873B1 (en) |
DE (2) | DE3422613A1 (en) |
NO (1) | NO172757C (en) |
Families Citing this family (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
DE3720330A1 (en) * | 1987-06-19 | 1988-12-29 | Huels Chemische Werke Ag | METHOD FOR OBTAINING PETROLEUM FROM AN UNDERGROUND STOCK WITH TENSIDES |
WO1989012158A1 (en) * | 1988-06-02 | 1989-12-14 | Chevron Research Company | Miscible gas enhanced oil recovery method using ethoxylated alkylphenol sulfonate |
US4836283A (en) * | 1988-06-08 | 1989-06-06 | The Standard Oil Company | Divalent ion tolerant aromatic sulfonates |
US4894173A (en) * | 1988-06-08 | 1990-01-16 | The Standard Oil Company | Divalent ion tolerant aromatic sulfonates |
US6439843B1 (en) | 2000-11-16 | 2002-08-27 | Ametek, Inc. | Motor/fan assembly having a radial diffuser bypass |
DE102013007680A1 (en) | 2013-05-03 | 2014-11-06 | Tougas Oilfield Solutions Gmbh | Electrolyte-containing aqueous polymer solution and process for the tertiary production of crude oil |
Family Cites Families (3)
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US3811505A (en) * | 1973-01-29 | 1974-05-21 | Texaco Inc | Surfactant oil recovery process usable in formations containing water having high concentrations of polyvalent ions such as calcium and magnesium |
DE2558548A1 (en) * | 1975-03-19 | 1976-09-30 | Texaco Development Corp | Sec. extn. of oil by flooding with water - contg. sulphonated ethylene oxide adduct of an alkyl phenol |
US3981361A (en) * | 1975-07-31 | 1976-09-21 | Exxon Production Research Company | Oil recovery method using microemulsions |
-
1984
- 1984-06-19 DE DE19843422613 patent/DE3422613A1/en not_active Withdrawn
-
1985
- 1985-06-13 EP EP85107314A patent/EP0167873B1/en not_active Expired
- 1985-06-13 DE DE8585107314T patent/DE3560084D1/en not_active Expired
- 1985-06-18 NO NO852456A patent/NO172757C/en unknown
Also Published As
Publication number | Publication date |
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NO852456L (en) | 1985-12-20 |
EP0167873A1 (en) | 1986-01-15 |
NO172757C (en) | 1993-09-01 |
DE3422613A1 (en) | 1985-12-19 |
EP0167873B1 (en) | 1987-03-04 |
DE3560084D1 (en) | 1987-04-09 |
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