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Process for removing hydrogen sulfide in crude oil

a technology of crude oil and hydrogen sulfide, which is applied in the field of crude oil removal methods, can solve the problems of incomplete hydrogen sulfide scavenging, high corrosion, and additional health concerns of aldehydes, and achieve the effect of reducing the amount of hydrogen sulfid

Inactive Publication Date: 2011-06-30
GENERAL ELECTRIC CO
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  • Summary
  • Abstract
  • Description
  • Claims
  • Application Information

AI Technical Summary

Benefits of technology

"The patent describes a method for reducing the amount of hydrogen sulfide in crude oil. This is done by adding a special composition to the oil that captures the sulfide and removes it from the oil. The composition includes glyoxal and a quaternary ammonium salt. This process helps to quickly and effectively remove the sulfide without creating any unwanted byproducts."

Problems solved by technology

Crude oil may contain hydrogen sulfide, which is highly corrosive in the presence of water and poisonous in very small concentrations.
The risk of exposure to hydrogen sulfide from handling crude oil is a health and safety concern during storage, transportation (shipping, truck or pipeline) and processing of the crude oil.
However, triazines release amines into the liquid hydrocarbon media and residual triazines thermally decompose to release additional amines into the liquid hydrocarbon media and may pose additional health concerns.
The free amines can form salts, which deposit on the processing equipment and cause corrosion.
Aldehydes can have slower reaction kinetics and may have incomplete hydrogen sulfide scavenging.

Method used

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Examples

Experimental program
Comparison scheme
Effect test

example 1

[0027]Hydrogen sulfide scavenging tests were performed on a crude oil containing 500 ppm hydrogen sulfide in the liquid phase from a Texas refinery in Valero. Testing was performed using the modified ASTM 5705-95 test that measures vapor phase H2S two hours after treatment (140° F.) via dragger tube. Results are shown in Table 1.

TABLE 1H2S ScavengerSample(1000 ppm)Residual H2S (ppm)CE-1MEA1 triazine400CE-2Triazine 8411C2120CE-3MMA3 triazine + Catalyst4200CE-4MEA1 triazine + Catalyst4200CE-5Glyoxal9501Glyoxal + Catalyst41401MEA is monoethanol amine2Triazine 8411C is available commercially from Clearwater, Inc as Sulfa-Clear 8411C.3MMA is monomethyl amine4Catalyst is cocoalkyldimethylbenzyl ammonium chloride (Arquad ® DMCB-80) at 1.6% by weight treatment level (actives basis) based on the weight of the triazine or glyoxal.

[0028]Sample 1 has comparable results to the use of a triazine in reducing hydrogen sulfide, but the catalyzed glyoxal can be removed in an aqueous phase; whereas, t...

example 2

[0029]The concentration of the hydrogen sulfide in the vapor phase was determined at different levels of treatment dosages after 1 hour and 2 hours for samples 1 and comparative examples CE-1 and CE-3, as shown in Table 2.

TABLE 2CE-1CE-3Sample 1CE-1CE-3Sample 1DosagesH2S levelH2S levelH2S levelH2S levelH2S levelH2S level(ppm)(ppm) @ 1 hour(ppm) @ 1 hour(ppm) @ 1 hour(ppm) @ 2 hours(ppm) @ 2 hours(ppm) @ 2 hours05005005005005005005001601006012080201000202020555

[0030]The samples reduce and control the hydrogen sulfide level. Sample 1 has comparable results to CE-1 and CE-3. However, Sample 1 can be removed in a aqueous phase and does not generate amines like the triazine samples will.

example 3

[0031]5 g of H2S was bubbled into a 2 L flask containing 1 L of a commercially available raw crude sample containing 2S concentration in the H2S-infused crude was 3940 μg / ml.

[0032]A demulsifier was added to the H2S-infused crude oil in the amounts shown in Table 3.

[0033]5% by volume wash water was mixed with glyoxal and cocoalkyldimethylbenzyl ammonium chloride, as shown in Table 3, and added to the H2S-infused crude oil. The wash water was mixed with the H2S-infused crude oil at 4000 rpm for 2 seconds, grids on, and heated to 130° C. at a pressure of 4 psi to form an emulsion.

[0034]The emulsion was allowed to sit for 32 minutes to separate the water phase from the crude oil. A water drop reading was performed to test the emulsion separation and is shown in Table 4. The water phase was removed from the separated emulsion and observed for clarity as shown in Table 3.

TABLE 3Demulsifier1Treatmeny3Mean Water DropSeparatedSample(ppm)2(ppm)2(ml)water ClarityBlank002.73ClearCE-8604.50Clear...

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Abstract

A method for reducing the amount of hydrogen sulfide present in crude oil includes adding a hydrogen sulfide scavenger composition to the crude oil to capture the hydrogen sulfide, migrating the captured sulfides to an aqueous phase and removing the aqueous phase from the crude oil. The hydrogen sulfide scavenger composition includes glyoxal and a quaternary ammonium salt.

Description

FIELD OF THE INVENTION[0001]This invention relates generally to methods for removing hydrogen sulfide and more particularly, to removing hydrogen sulfide from crude oil.BACKGROUND OF THE INVENTION[0002]Crude oil may contain hydrogen sulfide, which is highly corrosive in the presence of water and poisonous in very small concentrations. The risk of exposure to hydrogen sulfide from handling crude oil is a health and safety concern during storage, transportation (shipping, truck or pipeline) and processing of the crude oil.[0003]Hydrogen sulfide scavengers are used to remove hydrogen sulfide from the crude oil. Typical hydrogen sulfide scavengers are triazines and aldehydes. However, triazines release amines into the liquid hydrocarbon media and residual triazines thermally decompose to release additional amines into the liquid hydrocarbon media and may pose additional health concerns. The free amines can form salts, which deposit on the processing equipment and cause corrosion. Aldehy...

Claims

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Application Information

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Patent Type & Authority Applications(United States)
IPC IPC(8): C10G33/00
CPCC10G29/20
Inventor KARAS, LAWRENCE JOHNGOLIASZEWSKI, ALAN E.
Owner GENERAL ELECTRIC CO
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