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51318-10583-A Comparison of Chemistries Intended to Treat Reservoir Souring

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Novel compounds proven to reduce H2S production are compared to chemistries currently employed to prevent sulfidogenesis. 

Product Number: 51318-10583-SG
Author: Alicia M. Jones / Brett Geissler / Renato De Paula
Publication Date: 2018
Industry: Oil and Gas Production
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The presence of hydrogen sulfide (H2S) in a reservoir poses a major threat to oilfield asset integrity and oil and gas production. In addition to contributing to corrosion, H2S is extremely toxic and devalues produced fluids and gases. Not managing the consequences of a sour reservoir can eventually lead to costly well shut-ins and lost production time. While H2S can be formed through natural chemical reactions, a varied population of microorganisms capable of metabolizing an array of sulfur compounds is responsible for the biotic production of H2S. Current chemical treatment options for remediation of biotic reservoir souring include targeting microbial populations with a biocide or using calcium nitrate to selectively grow microorganisms that metabolize nitrate instead of sulfur compounds. We have recently identified a number of novel compounds that have been proven successful in the laboratory to prevent H2S production by directly targeting the sulfate-reducing population. In this study, we compare these novel compounds to chemistries currently employed to prevent sulfidogenesis, and we introduce an increased-throughput screening method to evaluate sulfide inhibition. Since the novel compounds consistently performed well in synthetic brine compared to other commonly used chemistries, we also provide results detailing the efficacy of these novel compounds in a variety of other conditions as well. These findings further expand our understanding of the existing and potential treatment strategies intended to combat the deleterious effects of biotic reservoir souring.

Key words: sulfate-reducing bacteria, hydrogen sulfide, reservoir souring, calcium nitrate, biocide

 

The presence of hydrogen sulfide (H2S) in a reservoir poses a major threat to oilfield asset integrity and oil and gas production. In addition to contributing to corrosion, H2S is extremely toxic and devalues produced fluids and gases. Not managing the consequences of a sour reservoir can eventually lead to costly well shut-ins and lost production time. While H2S can be formed through natural chemical reactions, a varied population of microorganisms capable of metabolizing an array of sulfur compounds is responsible for the biotic production of H2S. Current chemical treatment options for remediation of biotic reservoir souring include targeting microbial populations with a biocide or using calcium nitrate to selectively grow microorganisms that metabolize nitrate instead of sulfur compounds. We have recently identified a number of novel compounds that have been proven successful in the laboratory to prevent H2S production by directly targeting the sulfate-reducing population. In this study, we compare these novel compounds to chemistries currently employed to prevent sulfidogenesis, and we introduce an increased-throughput screening method to evaluate sulfide inhibition. Since the novel compounds consistently performed well in synthetic brine compared to other commonly used chemistries, we also provide results detailing the efficacy of these novel compounds in a variety of other conditions as well. These findings further expand our understanding of the existing and potential treatment strategies intended to combat the deleterious effects of biotic reservoir souring.

Key words: sulfate-reducing bacteria, hydrogen sulfide, reservoir souring, calcium nitrate, biocide

 

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51318-10586-Mechanistic study of microbiologically influenced corrosion

Product Number: 51318-10586-SG
Author: Jialin Liu / Wenwen Dou / Ru Jia / Xiaogang Li / Sith Kumseranee / Suchada Punpruk / Tingyue Gu
Publication Date: 2018
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This study demonstrates that the mechanisms of microbiologically influenced corrosion (MIC) by Desulfovibrio vulgaris, a sulfate reducing bacterium (SRB), against X65 carbon steel and pure copper belong to two different types of MIC.
Picture for Investigation of the impact of an enhanced oil recovery polymer on microbial growth and MIC
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51318-10567-Investigation of the impact of an enhanced oil recovery polymer on microbial growth and MIC

Product Number: 51318-10567-SG
Author: Ru Jia / Dongqing Yang / Hasrizal Bin Abd Rahman / Tingyue Gu
Publication Date: 2018
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A commercial cellulose-based polymer (carboxymethyl cellulose sodium) was tested to see whether it could be utilized by an oilfield biofilm consortium including sulfate reducing bacteria.
Picture for CALCIUM CARBONATE SCALE INHIBITION: EFFECTS OF EOR CHEMICALS
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51318-10546-CALCIUM CARBONATE SCALE INHIBITION: EFFECTS OF EOR CHEMICALS

Product Number: 51318-10546-SG
Author: Qiwei Wang / Waleed Al-Nasser / Tao Chen / Feng Liang
Publication Date: 2018
$20.00

Laboratory investigation on the impacts of enhanced oil recovery (EOR) chemicals, i.e., surfactant and polymer, on calcium carbonate scale formation and inhibition.
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