Multifunctional Chemical for Simultaneous Dissolution of Iron Sulfide, Corrosion Inhibition, and Scale Inhibition

2019 ◽  
Author(s):  
Patrick Rodgers ◽  
Brian Lundy ◽  
Sunder Ramachandran ◽  
James Ott ◽  
David Poelker ◽  
...  
Keyword(s):  
Corrosion Inhibition ◽  
Iron Sulfide ◽  
Scale Inhibition ◽  
Sulfide Corrosion ◽  
Simultaneous Dissolution

Research on Corrosion and Scale Inhibition Performance of HEDP

2012 ◽  
Vol 535-537 ◽  
pp. 1180-1184
Author(s):  
Mao Dong Li ◽  
Bin Zeng ◽  
Lin Yang ◽  
Jun Ming Zhao ◽  
Yu Hui Du ◽  
...  
Keyword(s):  
Corrosion Inhibition ◽  
Concentration Ratio ◽  
Inhibition Efficiency ◽  
Total Iron ◽  
Water Medium ◽  
Boiler Water ◽  
Inhibition Effect ◽  
Scale Inhibition ◽  
Industrial Boiler ◽  
Inhibition Performance

The static scale inhibition method will be used to evaluate the scale inhibition performance of HEDP. In order to study the corrosion inhibition of 20A steel with additive of HEDP in the industrial boiler water medium，the total iron ions in the solution are determined through autoclave static experiments. The results indicated that the scale inhibition efficiency，in the simulation boiler water with a certain concentration ratio and temperature，reached the maximum when CHEDP is 7 mg/L. It has a good corrosion inhibition effect on the 20A steel when the HEDP concentration exceeds 15ppm.

Iron Sulfide Scale Inhibition: Limitations at Sour Conditions

2020 ◽  
Author(s):  
Yaser K. Alduailej ◽  
Kenneth S. Sorbie
Keyword(s):  
Iron Sulfide ◽  
Scale Inhibition

High Temperature Sulfide Corrosion In Catalytic Reforming of Light Naphthas★,—A Contribution to the Work of NACE Task Group T-5B-2 on Sulfide Corrosion at High Temperatures and Pressures in the Petroleum Industry from Humble Oil and Refining Co., Baytown, Texas*

CORROSION ◽  
1957 ◽  
Vol 13 (1) ◽  
pp. 53-58 ◽  
Author(s):  
CECIL PHILLIPS
Keyword(s):  
Hydrogen Sulfide ◽  
Iron Sulfide ◽  
Petroleum Industry ◽  
Carbon Steels ◽  
Corrosion Rates ◽  
Naphtha Reforming ◽  
Chromium Alloys ◽  
Sulfide Corrosion ◽  
Sulfide Content ◽  
Hydrogen Sulfide Content

Abstract When a catalytic reformer at Humble Oil & Refining Company's Baytown, Texas plant showed alarming pressure drop across the reactors after about 50 days' operation principally as a result of plugging with iron sulfide scale, immediate steps were taken to investigate the source of scale and the importance of metal losses occurring in the system. Over 600 pounds of iron dust was removed from the reactor and the unit put back in operation. In a month's time it was necessary to screen the catalyst again. Heavy scale was found in the first exchanger on the reactor effluent stream both from the tubes and deposited from piping upstream. Catalyst was channeled and plugged. When it became apparent the scaling was the result of sulfide attack and possibly severe corrosion in the furnace tubes and other components a testing program was begun. Several materials were tested at various locations in the stream by the electrical resistance method. Hydrogen sulfide content of the naphtha charge and recycle gas was determined. Corrosion rates during operation on heavy naphtha varied from 0.15 to 0.4-inch on carbon steel and chrome alloys but the rate on 18-8 was about one-tenth that of the other metals. Chromium alloys through 12 percent in many instances showed corrosion rates higher than those of carbon steels. In a laboratory pilot unit, tests indicated that aluminized steel generally showed good resistance and that hydrogen sulfide concentrations under 0.008 mol percent did not cause appreciable damage at temperatures about 1000 F. Humble plans to install a hydrofining unit to reduce sulfur content of the naphtha to about 40 ppm before it is charged to the naphtha reforming process. 3.2.2

Assessment of Enhanced-Oil-Recovery-Chemicals Production and its Potential Effect on Upstream Facilities

SPE Journal ◽  
2019 ◽  
Vol 24 (03) ◽  
pp. 1037-1056 ◽  
Author(s):  
Abdulkareem M. AlSofi ◽  
Ali M. AlKhatib ◽  
Hassan A. Al-Ajwad ◽  
Qiwei Wang ◽  
Badr H. Zahrani
Keyword(s):  
Side Effects ◽  
Enhanced Oil Recovery ◽  
Corrosion Inhibition ◽  
Oil Recovery ◽  
Produced Water ◽  
Water Separation ◽  
Scale Inhibition ◽  
Chemical Eor ◽  
Oil Water Separation ◽  
Oil Water

Summary Review of past chemical-enhanced-oil-recovery (EOR) projects illustrates that chemical-EOR implementation can result in produced-fluid-handling issues. However, in all projects such issues were resolved, mainly through a combination of improved demulsifiers and oversized vessels. In previous work, we have demonstrated the potential of surfactant/polymer flooding for a high-temperature/high-salinity carbonate. In consideration of future plans to pilot the process, further assessments were conducted to evaluate any side effects of these EOR chemicals on upstream facilities and determine mitigation plans if needed. In this work, we initially conduct a critical review of past experience. Then, we investigate the surfactant/polymer compatibility with the additives used in processing facilities for demulsification and scale and corrosion inhibition as well as the possible effect of surfactant/polymer on oil/water separation, metal corrosion, and scale inhibition. For this purpose, we first perform a sensitivity-based simulation study to estimate the volumes of produced EOR chemicals. Second, a compatibility study is conducted to evaluate EOR chemical compatibility with oilfield additives (i.e., demulsifier, corrosion inhibitor, and scale inhibitor). Third, bottle tests are conducted using surfactant/polymer solutions prepared in both injection and produced water to evaluate the effect of EOR chemicals on oil/water separation. Separated-water qualities are also evaluated using solvent extraction followed by ultraviolet (UV) visibility testing. Fourth, static autoclave and dynamic rotating tests are performed to evaluate the possible side effects of EOR chemicals on corrosion inhibition. Finally, static bottle and dynamic tube tests are performed to evaluate the possible side effects of EOR chemicals on scale inhibition; these observations are supported by characterization of precipitates using environmental scanning electron microscopy (ESEM) and X-ray diffraction (XRD). Depending on simulation, the peak polymer and surfactant concentrations at the separation plant are 83 and 40 ppm, respectively. The sensitivity study suggests a worst-case scenario in which peak polymer and surfactant concentrations of 174 and 128 ppm are produced. Compatibility testing confirms the compatibility of EOR chemicals with the additives used in upstream facilities. In those tests, neither precipitation nor phase separation is observed. Bottle tests indicate an overall negligible effect on oil/water-separation speed. However, analyses of separated-water quality indicated a noteworthy deterioration in separated-water qualities. Oil-in-water concentrations increase from 100 to 750 ppm and from 300 to 450 ppm at injection- and produced-water salinities, respectively. Furthermore, corrosion tests suggest that surfactant/polymer presence results in a significant reduction in corrosion rates by 70 and 86% at static and dynamic conditions, respectively, without any pitting issues. Finally, static and dynamic scale-inhibition studies performed at exacerbated conditions suggest that EOR chemicals can reduce the effectiveness of scale inhibitors. In static scaling tests, the effectiveness of the base polyacrylate inhibitor diminishes completely. However, the same degree of inhibition was achieved by switching to phosphonate inhibitors, but at a slightly higher dosage between 5 and 15 mg/L. In dynamic scaling tests, the base polyacrylate inhibitor failed at all tested dosages up to 100 mg/L. However, the alternative phosphonate inhibitors passed at dosages between 20 and 45 mg/L. Such effects can be attributed to changes in scale morphology and polymorphs, as demonstrated by the XRD and ESEM results. On the basis of those results, we conclude that the selected surfactant/polymer implementation will have a manageable effect on separation facilities. Finally, this work provides an experimental protocol to evaluate the potential side effects of a chemical-EOR process on upstream facilities.

Synthesis of polyaspartic acid–aminobenzenesulfonic acid grafted copolymer and its scale inhibition performance and dispersion capacity

2011 ◽  
Vol 64 (2) ◽  
pp. 423-430 ◽  
Author(s):  
Ying Xu ◽  
Lina Wang ◽  
Linlin Zhao ◽  
Yuanchen Cui
Keyword(s):  
Corrosion Inhibition ◽  
Graft Copolymer ◽  
Polyaspartic Acid ◽  
Copolymer Solution ◽  
Sulfonic Group ◽  
Grafted Copolymer ◽  
Scale Inhibition ◽  
Dispersion Capacity ◽  
Inhibition Performance ◽  
Inhibition Ability

Polysuccinimide (abridged as PSI) was synthesized by urea and maleic anhydride. Aminobenzenesulfonic acid (ABSA) was introduced at different mole ratio to PSI to generate polyaspartic acid (abridged as PASP)/ABSA graft copolymer. The scale inhibition behavior of resultant PASP/ABSA copolymer was evaluated by using static scale inhibition method. The transmittance of the supernatant of the copolymer solution was measured to evaluate its dispersion ability for ferric oxide. The corrosion inhibition performance of the copolymer for iron plates immersed in the refined testing water (including 0.555 g of CaCl2·2H2O, 0.493 g of MgSO4·7H2O, 50 mg PASP/ABSA graft copolymer and 0.168 g of NaCl) was tested. It was found that PASP/ABSA copolymer was able to efficiently inhibit CaCO3 and Ca3(PO4)2 scales and had good corrosion inhibition ability as well, and it also had good dispersion ability for Fe2O3. Besides, the inhibition efficiency of PASP/ABSA against CaCO3 and Ca3(PO4)2 scales and its dispersion capacity for Fe2O3 was highly dependent on dosage. The reason may lie in that PASP/ABSA copolymer simultaneously possesses carboxylic ion and sulfonic group which can chelate Ca2+ to form stabilized and dissoluble chelates, resulting in increase of solubility of calcium salts in water. Also it may lie in that the introduction of acidic hydrophilic sulfonic group with a strong electrolytic capacity into PASP molecule simultaneously enhances the dispersion of the inhibitor molecules and hinders the formation of Ca3(PO4)2 scale.

Application of 1-hydroxyethylidene-1, 1-diphosphonic acid in boiler water for industrial boilers

2013 ◽  
Vol 67 (7) ◽  
pp. 1544-1550 ◽  
Author(s):  
Bin Zeng ◽  
Mao-dong Li ◽  
Zhi-ping Zhu ◽  
Jun-ming Zhao ◽  
Hui Zhang
Keyword(s):  
Water Treatment ◽  
Carbon Steel ◽  
Corrosion Inhibition ◽  
Test Temperature ◽  
Experimental Results ◽  
Diphosphonic Acid ◽  
Boiler Water ◽  
Inhibition Effect ◽  
Scale Inhibition ◽  
Industrial Boilers

The primary method used for boiler water treatment is the addition of chemicals to industrial boilers to prevent corrosion and scaling. The static scale inhibition method was used to evaluate the scale inhibition performance of 1-hydroxyethylidene-1, 1-diphosphonic acid (HEDP). Autoclave static experiments were used to study the corrosion inhibition properties of the main material for industrial boilers (20# carbon steel) with an HEDP additive in the industrial boiler water medium. The electrochemical behavior of HEDP on carbon steel corrosion control was investigated using electrochemical impedance spectroscopy and Tafel polarization techniques. Experimental results indicate that HEDP can have a good scale inhibition effect when added at a quantity of 5 to 7 mg/L at a test temperature of not more than 100 °C. To achieve a high scale inhibition rate, the HEDP dosage must be increased when the test temperature exceeds 100 °C. Electrochemical and autoclave static experimental results suggest that HEDP has a good corrosion inhibition effect on 20# carbon steel at a concentration of 25 mg/L. HEDP is an excellent water treatment agent.

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