Corrosion protection. Carbon and low alloy steels for use in hydrogen sulfide containing environments in oil and gas production. Materials and test methods. Guidelines

2001 ◽  
Keyword(s):  
Hydrogen Sulfide ◽  
Corrosion Protection ◽  
Oil And Gas ◽  
Test Methods ◽  
Gas Production ◽  
Low Alloy Steels ◽  
Oil And Gas Production ◽  
Alloy Steels

scholarly journals Hydrogen sulfide formation in oil and gas

2016 ◽  
Vol 94 (4) ◽  
pp. 406-413 ◽  
Author(s):  
Robert A. Marriott ◽  
Payman Pirzadeh ◽  
Juan J. Marrugo-Hernandez ◽  
Shaunak Raval
Keyword(s):  
Hydrogen Sulfide ◽  
Sulfate Reduction ◽  
Oil Sands ◽  
Oil And Gas ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Ionic Strength Effect ◽  
Thermochemical Sulfate Reduction ◽  
Fracture Fluid

Hydrogen sulfide (H2S) can be a significant component of oil and gas upstream production, where H2S can be naturally generated in situ from reservoir biomass and from sulfate-containing minerals through microbial sulfate reduction and (or) thermochemical sulfate reduction. On the other hand, the technologies employed in oil and gas production, especially from unconventional resources, also can contribute to generation or delay of appearance of H2S. Steam-assisted gravity drainage and hydraulic fracturing used in production of oil sands and shale oil/gas, respectively, can potentially convert the sulfur content of the petroleum into H2S or contribute excess amounts of H2S during production. A brief overview of the different classes of chemical reactions involved in the in situ generation and release of H2S is provided in this work. Speciation calculations and reaction mechanisms are presented to explain why thermochemical sulfate reduction progresses at faster rates under low pH. New studies regarding the degradation of a hydraulic fracture fluid additive (sodium dodecly sulfate) are reported for T = 200 °C, p = 17 MPa, and high ionic strengths. The absence of an ionic strength effect on the reaction rate suggests that the rate-limiting step involves the reaction of neutral species, such as elemental sulfur. This is not the case with other thermochemical sulfate reduction studies at T > 300 °C. These two different kinetic regimes complicate the goal of extrapolating laboratory results for field-specific models for H2S production.

scholarly journals Measurements of hydrogen sulfide (H<sub>2</sub>S) using PTR-MS: calibration, humidity dependence, inter-comparison and results from field studies in an oil and gas production region

2014 ◽  
Vol 7 (10) ◽  
pp. 3597-3610 ◽  
Author(s):  
R. Li ◽  
C. Warneke ◽  
M. Graus ◽  
R. Field ◽  
F. Geiger ◽  
...  
Keyword(s):  
Hydrogen Sulfide ◽  
Oil And Gas ◽  
Gas Production ◽  
Point Sources ◽  
Air Pollutant ◽  
Oil Field ◽  
Oil And Gas Production ◽  
Mixing Ratios ◽  
Humidity Dependence ◽  
Uintah Basin

Abstract. Natural gas production is associated with emissions of several trace gases, some of them classified as air toxics. While volatile organic compounds (VOCs) have received much attention, hydrogen sulfide (H2S) can also be of concern due to the known health impacts of exposure to this hazardous air pollutant. Here, we present quantitative, fast time-response measurements of H2S using proton-transfer-reaction mass-spectrometry (PTR-MS) instruments. An ultra-light-weight PTR-MS (ULW-PTR-MS) in a mobile laboratory was operated for measurements of VOCs and H2S in a gas and oil field during the Uintah Basin Winter Ozone Study (UBWOS) 2012 campaign. Measurements of VOCs and H2S by a PTR-MS were also made at the Horse Pool ground site in the Uintah Basin during UBWOS 2013. The H2S measurement by PTR-MS is strongly humidity dependent because the proton affinity of H2S is only slightly higher than that of water. The H2S sensitivity of PTR-MS ranged between 0.6–1.4 ncps ppbv−1 during UBWOS 2013. We compare the humidity dependence determined in the laboratory with in-field calibrations and determine the H2S mixing ratios for the mobile and ground measurements. The PTR-MS measurements at Horse Pool are evaluated by comparison with simultaneous H2S measurements using a PTR time-of-flight MS (PTR-ToF-MS) and a Picarro cavity ring down spectroscopy (CRDS) instrument for H2S / CH4. On average 0.6 ± 0.3 ppbv H2S was present at Horse Pool during UBWOS 2013. The correlation between H2S and methane enhancements suggests that the source of H2S is associated with oil and gas extraction in the basin. Significant H2S mixing ratios of up to 9 ppmv downwind of storage tanks were observed during the mobile measurements. This study suggests that H2S emissions associated with oil and gas production can lead to short-term high levels close to point sources, and elevated background levels away from those sources. In addition, our work has demonstrated that PTR-MS can make reliable measurements of H2S at levels below 1 ppbv.

scholarly journals Measurements of hydrogen sulfide (H<sub>2</sub>S) using PTR-MS: calibration, humidity dependence, inter-comparison and results from field studies in an oil and gas production region

2014 ◽  
Vol 7 (6) ◽  
pp. 6205-6243 ◽  
Author(s):  
R. Li ◽  
C. Warneke ◽  
M. Graus ◽  
R. Field ◽  
F. Geiger ◽  
...  
Keyword(s):  
Hydrogen Sulfide ◽  
Oil And Gas ◽  
Gas Production ◽  
Point Sources ◽  
Air Pollutant ◽  
Oil Field ◽  
Oil And Gas Production ◽  
Mixing Ratios ◽  
Humidity Dependence ◽  
Uintah Basin

Abstract. Natural gas production is associated with emissions of several trace gases, some of them classified as air toxics. While volatile organic compounds (VOCs) have received much attention, hydrogen sulfide (H2S) can also be of concern due to the known health impacts of exposure to this hazardous air pollutant. Here, we present quantitative, fast time-response measurements of H2S using Proton-Transfer-Reaction Mass-Spectrometry (PTR-MS) instruments. An Ultra-Light-Weight PTR-MS (ULW-PTR-MS) in a mobile laboratory was operated for measurements of VOCs and H2S in a gas and oil field during the Uintah Basin Winter Ozone Study (UBWOS) 2012 campaign. Measurements of VOCs and H2S by a PTR-MS were also made at the Horse Pool ground site in the Uintah Basin during UBWOS 2013. The H2S measurement by PTR-MS is strongly humidity dependent because the proton affinity of H2S is only slightly higher than that of water. The H2S sensitivity of PTR-MS ranged between 0.6–1.4 ncps ppbv−1 (normalized counts per second/parts per billion by volume) during UBWOS 2013. We compare the humidity dependence determined in the laboratory with in-field calibrations and determine the H2S mixing ratios for the mobile and ground measurements. The PTR-MS measurements at Horse Pool are evaluated by comparison with simultaneous H2S measurements using a PTR Time-of-Flight MS (PTR-ToF-MS) and a Picarro cavity ring down spectroscopy (CRDS) instrument for H2S/CH4. On average 0.6 ± 0.3 ppbv H2S was present at Horse Pool during UBWOS 2013. The correlation between H2S and methane enhancements suggests that the source of H2S is associated with oil and gas extraction in the basin. Significant H2S mixing ratios of up to 9 ppmv downwind of storage tanks were observed during the mobile measurements. This study suggests that H2S emissions associated with oil and gas production can lead to short-term high levels close to point sources, and elevated background levels away from those sources. In addition, our work has demonstrated that PTR-MS can make reliable measurements of H2S at levels below 1 ppbv.

Corrosion of downhole equipment in hydrogen sulfur-containing environments

2021 ◽  
Vol 26 (2) ◽  
Keyword(s):  
Hydrogen Sulfide ◽  
Oil And Gas ◽  
Calculated Data ◽  
Field Tests ◽  
Physicochemical Characteristics ◽  
Gas Production ◽  
Simultaneous Action ◽  
Corrosive Environment ◽  
Oil And Gas Production ◽  
Dynamic Matrix

Complications associated with the corrosive environment, according to JSC Orenburgneft, NK Rosneft for the period 01.01.2021, are among the prevailing ones at oil and gas production facilities and share the 1st place with the scaling factor - 26% of the complicated mechanized well stock. Downhole equipment failures due to corrosion account for 20% of the total number of fixed failures in 2020. By the type of exposure to a corrosive environment at the fields operated within the perimeter of Rosneft, JSC Orenburgneft, hydrogen sulfide and mixed corrosion (caused by simultaneous action of CO2 and H2S) are predominant. The article presents the calculated data on the physicochemical characteristics of aqueous solutions of H2S. The existing approaches for description of the mechanisms of hydrogen sulfide corrosion of oilfield equipment with examples of corrosive destruction at producing string are described A dynamic matrix of the various protection technologies and their applicability in hydrogen sulfide-containing environments is presented, which is used in the fields operated by PJSC NK Rosneft and filled according to the results of laboratory and pilot field tests. The criterions of attribution of equipment to abnormal fund on basis of classification of factors complicated exploitation and following determination of equipment category being used in localized norms of NK Rosneft are described.

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