Squeeze treatment for in situ scavenging of hydrogen sulfide
원문보기
IPC분류정보
국가/구분
United States(US) Patent
등록
국제특허분류(IPC7판)
E21B-043/25
C09K-008/52
C09K-008/528
출원번호
US-0108587
(2013-12-17)
등록번호
US-9631467
(2017-04-25)
발명자
/ 주소
Bailey, Joseph P.
Martinez, Aaron D.
Acosta Otero, Erick J.
Mukkamala, Ravindranath
Silvestri, Maximilian A.
Macias, Jose M.
출원인 / 주소
Ecolab USA Inc.
대리인 / 주소
Senniger Powers LLP
인용정보
피인용 횟수 :
0인용 특허 :
22
초록▼
A method of performing a squeeze treatment comprises pumping a treatment fluid under pressure through a wellbore into a subterranean formation, wherein the treatment fluid includes a hydrogen sulfide scavenging compound that adsorbs onto the subterranean formation in a region around the wellbore. Pr
A method of performing a squeeze treatment comprises pumping a treatment fluid under pressure through a wellbore into a subterranean formation, wherein the treatment fluid includes a hydrogen sulfide scavenging compound that adsorbs onto the subterranean formation in a region around the wellbore. Production fluids are then allowed to flow from the subterranean formation into the wellbore, wherein the production fluids contact the adsorbed hydrogen sulfide scavenging compound as the production fluids flow through the region around the wellbore, and wherein the production fluids contain hydrogen sulfide that reacts with the hydrogen sulfide scavenging compound to reduce an amount of hydrogen sulfide in the production fluids before the production fluids flow into the wellbore.
대표청구항▼
1. A squeeze treatment method for reducing the amount of hydrogen sulfide in a hydrocarbon-containing fluid, comprising: pumping a treatment fluid under pressure through a wellbore into a subterranean formation and maintaining the treatment fluid in the region around the wellbore for a predetermined
1. A squeeze treatment method for reducing the amount of hydrogen sulfide in a hydrocarbon-containing fluid, comprising: pumping a treatment fluid under pressure through a wellbore into a subterranean formation and maintaining the treatment fluid in the region around the wellbore for a predetermined period of time, wherein the treatment fluid includes a hydrogen sulfide scavenging compound that adsorbs onto the subterranean formation in a region around the wellbore;flowing production fluids from the subterranean formation into the wellbore, wherein the production fluids contact the adsorbed hydrogen sulfide scavenging compound as the production fluids flow through the region around the wellbore, wherein the production fluids contain hydrogen sulfide that reacts with the hydrogen sulfide scavenging compound to reduce an amount of hydrogen sulfide in the production fluids before the production fluids flow into the wellbore; andwherein the hydrogen sulfide scavenging compound is bis(hydroxymethyl)maleate, (2E,4E)-hydroxymethyl hexa-2,4-dienoate, (E)-hydroxymethyl but-2-3noate, (E)-bis(hydroxymethyl) O,O′(2-hydroxypropane-1,3-diyl)difumarate, hydroxymethyl 6-(2,5-dioxo-2,5-dihydro-1H-pyrrol-1-yl)hexanoate, sorbic acid, glycerol bis hemiformal mono phosphate ether, oligomeric glycerol bis hemiformal di-phosphate ether, glycerol bis hemiformal mono sulfate ether, oligomeric glycerol bis hemiformal di-sulfate ether, (2E,2′E)-4,4′-((2-hydroxypropane-1,3-diyl)bis(oxy))bis(4-oxobut-2-enoic acid), 1,3-bis(hydroxymethoxy)propan-2-yl propionate, oxybis(1-(hydroxymethoxy)propane-3,2-diyl) dipropionate, 1,1′-((oxybis(1-(hydroxymethoxy)propane-3,2-diyl))bis(oxy))bis(propan-1-ol), or a combination thereof. 2. The method of claim 1, wherein the treatment fluid is maintained in the region around the wellbore for a predetermined period of time to allow the hydrogen sulfide scavenging compound to absorb onto the subterranean formation. 3. The method of claim 2, wherein the predetermined period of time is between 12 and 16 hours. 4. The method of claim 2, wherein the predetermined period of time is greater than 16 hours. 5. The method of claim 1, wherein the treatment fluid includes between 10 and 15 volume percent of the hydrogen sulfide scavenging compound. 6. The method of claim 1, wherein the treatment fluid includes a mixture of water and ethanol. 7. The method of claim 1, wherein the treatment fluid includes a component selected from scale inhibitors, asphaltene inhibitors, biocides, and combinations thereof. 8. The method of claim 1, wherein the ratio of hydrogen sulfide scavenging compound to hydrogen sulfide is about 12:1 in the production fluid. 9. A squeeze treatment method for reducing the amount of hydrogen sulfide in a hydrocarbon-containing fluid comprising: pumping a treatment fluid under pressure through a wellbore into a subterranean formation and maintaining the treatment fluid in the region around the wellbore for a predetermined period of time, wherein the treatment fluid includes a hydrogen sulfide scavenging compound that adsorbs onto the subterranean formation in a region around the wellbore;flowing production fluids from the subterranean formation into the wellbore, wherein the production fluids contact the adsorbed hydrogen sulfide scavenging compound as the production fluids flow through the region around the wellbore, wherein the production fluids contain hydrogen sulfide that reacts with the hydrogen sulfide scavenging compound to reduce an amount of hydrogen sulfide in the production fluids before the production fluids flow into the wellbore;monitoring the concentration of hydrogen sulfide in the production fluids flowing from the subterranean formation through the wellbore; andin response to the concentration of hydrogen sulfide exceeding a threshold concentration, stopping the flow of production fluids from the subterranean formation into the wellbore, then pumping an additional amount of the treatment fluid under pressure through the wellbore into the subterranean formation, then maintaining the treatment fluid in the region around the wellbore for a predetermined period of time, and then restarting the flow of production fluids from the subterranean formation into the wellbore; andwherein the hydrogen sulfide scavenging compound is bis(hydroxymethyl)maleate, (2E,4E)-hydroxymethyl hexa-2,4-dienoate, (E)-hydroxymethyl but-2-3noate, (E)-bis(hydroxymethyl) O,O′(2-hydroxypropane-1,3-diyl)difumarate, hydroxymethyl 6-(2,5-dioxo-2,5-dihydro-1H-pyrrol-1-yl)hexanoate, sorbic acid, glycerol bis hemiformal mono phosphate ether, oligomeric glycerol bis hemiformal di-phosphate ether, glycerol bis hemiformal mono sulfate ether, oligomeric glycerol bis hemiformal di-sulfate ether, (2E,2′E)-4,4′-((2-hydroxypropane-1,3-diyl)bis(oxy))bis(4-oxobut-2-enoic acid), 1,3-bis(hydroxymethoxy)propan-2-yl propionate, oxybis(1-(hydroxymethoxy)propane-3,2-diyl) dipropionate, 1,1′-((oxybis(1-(hydroxymethoxy)propane-3,2-diyl))bis(oxy))bis(propan-1-ol), or a combination thereof. 10. The method of claim 9, wherein the hydrogen sulfide scavenging compound is glycerol bis hemiformal mono phosphate ether, oligomeric glycerol bis hemiformal di-phosphate ether, glycerol bis hemiformal mono sulfate ether, oligomeric glycerol bis hemiformal di-sulfate ether, or a combination thereof. 11. The method of claim 9, wherein the hydrogen sulfide scavenging compound is (2E,2′E)-4,4′-((2-hydroxypropane-1,3-diyl)bis(oxy))bis(4-oxobut-2-enoic acid), 1,3-bis(hydroxymethoxy)propan-2-yl propionate, oxybis(1-(hydroxymethoxy)propane-3,2-diyl) dipropionate, 1,1′-((oxybis(1-(hydroxymethoxy)propane-3,2-diyl))bis(oxy))bis(propan-1-ol), or a combination thereof. 12. The method of claim 9, wherein the hydrogen sulfide scavenging compound is bis(hydroxymethyl)maleate, (2E,4E)-hydroxymethyl hexa-2,4-dienoate, (E)-hydroxymethyl but-2-3 noate, (E)-bis(hydroxymethyl) O,O′-(2-hydroxypropane-1,3-diyl)difumarate, hydroxymethyl 6-(2,5-dioxo-2,5-dihydro-1H-pyrrol-1-yl)hexanoate, sorbic acid, or a combination thereof. 13. The method of claim 9, wherein the hydrogen sulfide scavenging compound is amine-free. 14. The method of claim 9, wherein the ratio of hydrogen sulfide scavenging compound to hydrogen sulfide is about 12:1 in the production fluid. 15. The method of claim 9, wherein the treatment fluid is maintained in the region around the wellbore for a predetermined period of time to allow the hydrogen sulfide scavenging compound to absorb onto the subterranean formation. 16. The method of claim 15, wherein the predetermined period of time is between 12 and 16 hours. 17. The method of claim 15, wherein the predetermined period of time is greater than 16 hours. 18. The method of claim 9, wherein the treatment fluid includes between 10 and 15 volume percent of the hydrogen sulfide scavenging compound. 19. The method of claim 9, wherein the treatment fluid includes a mixture of water and ethanol.
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이 특허에 인용된 특허 (22)
Hoffmann Hermann (Kelkheim(Taunus) DEX) Mabire Frederic (Arcueil FRX), Aqueous aldehyde solutions for trapping hydrogen sulfide in natural gas and crude oil producing plants.
Jenson Dale A. (Overland Park KS) Jezak Anne Z. (Mission KS) Massey Albert O. (Beaumont TX), Method of treating a spent caustic stream from a sour water stripper to reduce the sulfide content thereof.
Chapman Richard George (Weybridge GB2) Collins Ian Ralph (Hampton GB2) Goodwin Stephen Paul (London GB2) Lucy Andrew Richard (York GB2) Stewart Nevin John (Guildford GB2), Oil and gas field chemicals.
Collins Ian Ralph,GBX ; Stewart Nevin John,GBX, Process for increasing effectiveness of production chemicals by reducing number of squeezing and shut-in operations required to increase production rate from an oil well.
Savage David W. (Summit NJ) Sartori Guido (Linden NJ) Stogryn Eugene L. (Edison NJ), Process for the selective removal of hydrogen sulfide from gaseous mixtures with severely sterically hindered secondary.
Eric L. Winchester CA; Michael J. McMullin CA; Jeffrey K. Hum CA, Removing hydrogen sulfide from a gaseous mixture using ferric ions bonded to calcined diatomite.
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