CORROSION INHIBITION IN DEEP, HOT WYOMING WELLS
Abstract
Corrosion Inhibition In Deep, Hot Wyoming Wells Joe A. Kelley Joe A. Kelley Petrolite Corp. Search for other works by this author on: This Site Google Scholar Paper presented at the SPE Rocky Mountain Regional Meeting, Casper, Wyoming, May 1980. Paper Number: SPE-9035-MS https://doi.org/10.2118/9035-MS Published: May 14 1980 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Kelley, Joe A. "Corrosion Inhibition In Deep, Hot Wyoming Wells." Paper presented at the SPE Rocky Mountain Regional Meeting, Casper, Wyoming, May 1980. doi: https://doi.org/10.2118/9035-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu nav search search input Search input auto suggest search filter All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE Rocky Mountain Petroleum Technology Conference / Low Permeability Reservoirs Symposium Search Advanced Search Kelley, Joe A., Petrolite Corp. Petrolite Corp. Copyright 1980, American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc. Petroleum Engineers, Inc. This paper was presented at the SPE Rocky Mountain Regional Meeting, held in Casper, Wyoming, May 14–16, 1980. The material is subject to correction by the author. Permission to copy is restricted to an abstract of not more than 300 words. Write: 6200 N. Central Expressway, Dallas, Texas 75206.AbstractDownhole inhibitor treatment of several relatively deep, hot gas wells in Wyoming was used in a study of factors to consider in establishing an effective corrosion control program. Basically, one needs an effective inhibitor, a good application method, and a means to evaluate the lifetime of the treatment.IntroductionMany of the guidelines for estimating corrosivity in gas wells were developed in previous decades for reservoirs which were not nearly as deep or hot as many of the reservoirs being developed today. A generalization published in the Fifties stated, "sweet wells with a CO2 partial pressure less than 7 psi would not be corrosive". However, recent publications indicate this is an oversimplification since significant corrosion can occur at partial pressures below that. In addition to CO2 partial pressure, variables such as temperature, pressure, gas composition, production rates, velocity, and phase relationships production rates, velocity, and phase relationships take on new significance as deeper and hotter reservoirs are produced. Consequently, the methods to control corrosion should consider the effects of the above mentioned variables.To maintain a successful corrosion control program, several goals must be met: program, several goals must be met:An effective inhibitor must be used;A liquid inhibitor solution must contact the entire metal surface; andA monitoring program must be established to gauge treatment effectiveness and treatment lifetime under operating conditions.This paper describes some of the factors in the application of a batch treatment to control corrosion in several deep, hot wells in Central Wyoming. (Well conditions in Table 1). These wells are known to be corrosive but fortunately are in the temperature, pressure, production range where batch treatments pressure, production range where batch treatments can be practical.TREATMENT CONSIDERATIONSThe selection of an effective inhibitor was based on laboratory tests and experience in similar wells. A good discussion of problems associated with inhibitor selection based entirely on laboratory tests is in an article by Fincher, et al. From laboratory tests and field experience two inhibitors were chosen; one was totally oil soluble and the other oil soluble/water dispersible.The second step of the program was to insure the batch method allowed all of the metal surface to be contacted by inhibitor. This involved calculation of amount of inhibitor necessary to film the walls, shut-in time for inhibitor to fall to the bottom, and amount of solvent needed to maintain a liquid phase downhole. The use of sufficient solvent to maintain a liquid phase under all well conditions is often overlooked in the application of an inhibitor.The calculation of minimum amount of inhibitor needed and appropriate shut-in time was based on information gathered by several workers during batch treatment of gas wells. The studies have shown that a standing column of liquid will form and regress from the bottom of the column at a rate of 36 m/hr while a 0.76 mm film of liquid falls down the tubing at a rate of 760 to 823 m/hr. Due to the high bottomhole temperatures, the shut-in times were calculated to avoid contacting the formation with inhibitor to prevent any possibility of any unfavorable interactions. possibility of any unfavorable interactions. A computer program that takes into consideration the effects of pressure, temperature, gas composition, tubing size, well depth, and gas production was used to calculate the amount of carrier needed to saturate the gas phase and thus insure a liquid phase downhole. Keywords: Corrosion Inhibition, Production Chemistry, inhibitor, Corrosion Control Program, Upstream Oil & Gas, calculation, hydrogen probe, effective inhibitor, Material Performance, application Subjects: Production Chemistry, Metallurgy and Biology, Improved and Enhanced Recovery, Corrosion inhibition and management (including H2S and CO2) This content is only available via PDF. 1980. Society of Petroleum Engineers You can access this article if you purchase or spend a download.