Acid Corrosion in Wells (CO2, H2S): Metallurgical Aspects

Crolet, Jean-Louis

doi:10.2118/10045-pa

Cited by 31 publications

(16 citation statements)

References 5 publications

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“…Occurrences of high concentrations of CO 2 (and other acid gases) in other oil and gas fields, led to numerous investigations of the corrosion properties of the various steels used in the production infrastructure (e.g. Schremp & Roberson 1975;Crolet 1983Crolet , 1994EFCP 1994). This has allowed for the development of speciality steels more resistant to CO 2 corrosion -at least over the likely operational timescale of a hydrocarbon production facility.…”

Section: Observations From Various Industriesmentioning

confidence: 99%

“…SEM image of hydrated and set Class G Oilwell Cement after autoclaving for 24 hours at 7 MPa and 30 ~ Note euhedral portlandite crystals in low macroporosity CSH gel matrix. (Crolet 1983). Although corrosion rates of less that 0.1 mm/year may be acceptable over an assumed 30-year lifetime of a pipe or an old completion (Crolet 1994), localized corrosion may present specific problems.…”

Section: Observations From Various Industriesmentioning

confidence: 99%

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The impact of chemical reactions on CO ₂ storage in geological formations: a brief review

Rochelle

Czernichowski-Lauriol

Milodowski

2004

195

120

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The sequestration of CO 2 in the deep geosphere is one potential method for reducing anthropogenic emissions to the atmosphere without a drastic change in our energy-producing technologies. Immediately after injection, the CO 2 will be stored as a free phase within the host rock. Over time it will dissolve into the local formation water and initiate a variety of geochemical reactions. Some of these reactions could be beneficial, helping to chemically contain or 'trap' the CO 2 as dissolved species and by the formation of new carbonate minerals; others may be deleterious, and actually aid the migration of CO 2. It will be important to understand the overall impact of these competing processes. However, these processes will also be dependent upon the structure, mineralogy and hydrogeology of the specific lithologies concerned and the chemical stability of the engineered features (principally, the cement and steel components in the well completions). Therefore, individual storage operations will have to take account of local geological, fluid chemical and hydrogeological conditions. The aim of this paper is to review some of the possible chemical reactions that might occur once CO 2 is injected underground, and to highlight their possible impacts on long-term CO 2 storage.If sequestration of CO 2 is to be a practicable largescale disposal method, the CO 2 must remain safely underground, and not return to the atmosphere within relatively short timescales (e.g. thousands of years), so that natural buffering processes (e.g. oceanic and forestry sinks) have sufficient time to reduce global atmospheric CO 2 levels to environmentally acceptable levels. Indeed, acceptable performance will need to be demonstrated in order to satisfy operational, regulatory and public acceptance criteria. The track record of CO2-assisted enhanced oil recovery (EOR) operations and purposedesigned underground storage of natural gas shows that underground storage can be practicable and leakage minimized over 'industrial' time periods (e.g. tens of years). However, there is much less information for longer-term processes, and these must be understood, especially as CO 2 is more chemically reactive than methane.The injection of a relatively reactive substance such as CO 2 into the deep subsurface will result in chemical disequilibria and the initiation of various chemical reactions. It is important to understand the direction, rate and magnitude of such reactions both in terms of their impact upon the ability of a host formation to contain the injected CO 2 safely, and in terms of the longevity of CO 2 containment (e.g. Rochelle et al. 1999). Some reactions, such as the precipitation of CO 2 in secondary carbonate minerals, may be beneficial and aid containment. However, other reactions may result in mineral dissolution -facilitating the formation of migration pathways and so act to reduce containment. The aim of this paper is to highlight some of these processes, and to illustrate their possible impact on long-term CO 2 storage. It is hoped that...

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Section: Observations From Various Industriesmentioning

confidence: 99%

Section: Observations From Various Industriesmentioning

confidence: 99%

The impact of chemical reactions on CO ₂ storage in geological formations: a brief review

Rochelle

Czernichowski-Lauriol

Milodowski

2004

195

120

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“…Several evaluations of oilfield materials for use in H 2 S environments have been conducted. [15][16] Of particular interest is the work by Kane and Wilhelm 15 in which aspects of general corrosion; SSC; Stress Corrosion Cracking (SCC); and Hydrogen Embrittlement (HE) in H 2 S and CO 2 , and H 2 S and chloride environments are examined. In one part, the corrosion and cracking that can occur on high-alloy steels and the newer materials, for use in the completion of wells with a sour environment, as a result of acidizing operations are examined.…”

Section: Introductionmentioning

confidence: 99%

Acid Stimulation of Sour Wells

Delorey¹,

Vician²,

Metcalf³

2002

All Days

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractProduction of Hydrogen Sulfide (H 2 S) gas in oil and gas wells has increased over the last few years. These sour (H 2 S Producers) wells have been successfully acid stimulated for many years. Wellbore acid washes, high rate squeeze treatments and acid fracs have been the norm for stimulating wells in carbonate formations. However, to accomplish this there are many problems related to the interaction of the treatment fluids and the H 2 S. These can result in excessive corrosion, unwanted precipitants, metal cracking, etc.In recent years, the practice of drilling horizontal wells has led to the technique of underbalanced acid washing. Controlling corrosion, metal fatigue and unwanted precipitants when using this technique in sour formations presents a special challenge. The resulting interaction of the H 2 S and acid additives, especially corrosion inhibitors has been the primary focus of concern. This paper describes test equipment and procedures designed to investigate H 2 S and acid additive interactions. Test results with a range of inhibitors and additives designed to minimize formation damage and protect coiled tubing and tubular steels are provided. Specifically, weight loss, pitting and precipitation products are listed.

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“…The choice of X80 steel was motivated by its widespread application in construction of casings, tubing, pipe works and transport lines in the oil and gas industry. [8][9][10][11][12][13][14] On the other hand, the choice of Griffonia simplicifolia is due to the broad alkaloid composition which has been reported about the plant, especially the presence of 5-hydroxytryptophan. …”

mentioning

confidence: 99%

Solvents Effect on Thermal Stability and Electrochemical Behaviour of Griffonia Simplicifolia Extracts as Steel Corrosion Inhibitor in Acidic Environment

Ituen¹,

Akaranta²,

James³

2017

ECB

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Different solvents were used to extract Griffonia simplicifolia and tested corrosion inhibitors for as X80 steel in 1 M HCl solution. The corrosion tests were conducted by thermo-gravimetric analyses (TGA), electrochemical impedance spectroscopy (EIS) and potentiodynamic polarization (PDP) while the surface morphologies were checked by scanning electron microscopy (SEM). The essence was to investigate the effects of the solvents on the yield, phytochemical profile, corrosion inhibition properties and thermal stability of the extracts. The highest yields of 63.24 g kg -1 and 51.63 g kg -1 were obtained with seeds (SEGS) and leaves (LEGS) extracts respectively in ethanol-water (1:1) system. Acetone extract showed presence of all the tested phytochemicals namely alkaloids, tannins, saponins, glycosides, steroids and terpenoids. The highest inhibition efficiencies of 95.86 % (SEGS) and 82.14 % (LEGS) were obtained with acetone extracts. Acetone extract was also most thermally stable being 66.4 % (SEGS) and 50.05 % (LEGS) efficient at 90 C, followed by ethanol extract while methanol extract was least stable and least efficient. Inhibitors act as mixed type and their addition increased charge transfer resistance and decreased corrosion current density with respect to the free acid solution. Micrographs of the steel surface in some systems show evidence of slight surface protection by the inhibitors. It has been inferred from this study that both acetone and ethanol are better solvents for extraction of Griffonia simplicifolia based corrosion inhibitors.

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Acid Corrosion in Wells (CO2, H2S): Metallurgical Aspects

Cited by 31 publications

References 5 publications

The impact of chemical reactions on CO ₂ storage in geological formations: a brief review

The impact of chemical reactions on CO ₂ storage in geological formations: a brief review

Acid Stimulation of Sour Wells

Solvents Effect on Thermal Stability and Electrochemical Behaviour of Griffonia Simplicifolia Extracts as Steel Corrosion Inhibitor in Acidic Environment

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Acid Corrosion in Wells (CO2, H2S): Metallurgical Aspects

Cited by 31 publications

References 5 publications

The impact of chemical reactions on CO 2 storage in geological formations: a brief review

The impact of chemical reactions on CO 2 storage in geological formations: a brief review

Acid Stimulation of Sour Wells

Solvents Effect on Thermal Stability and Electrochemical Behaviour of Griffonia Simplicifolia Extracts as Steel Corrosion Inhibitor in Acidic Environment

Contact Info

Product

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The impact of chemical reactions on CO ₂ storage in geological formations: a brief review

The impact of chemical reactions on CO ₂ storage in geological formations: a brief review