By Harry G. Byars
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Extra info for Corrosion Control in Petroleum Production: Tpc Publication 5
Example text
NACE Standard RPO195-95, "Recommended Practice for Corrosion Control of Sucker Rods by Chemical Treatment" (Houston, TX: NACE, 1995). 2. NACE Standard MR0176 (latest edition), "Metallic Materials for Sucker Rod Pumps for Corrosive Oilfield Environments" (Houston,TX: NACE). 3. NACE Standard MR0175 (latest edition), "Sulfide Stress Cracking Resistant Metallic Materials for Oilfield Equipment" (Houston, TX: NACE). 4. : American Petroleum Institute). 5. API Specification 6A. "Specification for Wellhead and Christmas Tree Equipment" 16th ed.
Sour gas wells that do not produce associated hydrocarbon liquids should be considered corrosive, and protective measures taken. The choice for these situations has been either continuous inhibition or use of corrosion-resistant alloys. The presence of H2S in oil wells may or may not be a significant factor in weight loss/pitting corrosion depending upon the water phase pH and the presence or absence of oxygen. When reservoir pressure is less than the bubble point pressure, fresh water may condense from the associated gas while being produced and cause corrosion if buffers are not present (low levels of produced formation water).
Even tight, adherent scales can create problems if they form only in spots rather than uniformly over the metal surface. Sulfate-reducing bacteria (SRB) thrive under scales, sludge, sand, formation solids, and other debris, creating hydrogen sulfide (H2S) and causing localized pitting. 24 show the results of such bacterial activities. The line had been laid in a sandy area. Sand that had blown into the pipe during construction was not cleaned from the line before commissioning. The water contained an inactive strain of sulfate reducing bacteria.