Development, Testing and Field Application of a Novel Combination Foamer-Iron Sulfide Scale Inhibitor-Corrosion Inhibitor in East Texas

2017 ◽  
Author(s):  
Jonathan J. Wylde ◽  
Nick Turner ◽  
Mark Austill ◽  
Cyril Okocha ◽  
Nihal Obeyesekere
Keyword(s):  
Corrosion Inhibitor ◽  
Iron Sulfide ◽  
Field Application ◽  
East Texas ◽  
Scale Inhibitor

The Application of Corrosion and Scale Inhibitor to Circulating Water

2012 ◽  
Vol 610-613 ◽  
pp. 2591-2594
Author(s):  
Jia Guo Ren ◽  
Qian Qian Wu
Keyword(s):  
Water Treatment ◽  
Power Plant ◽  
Corrosion Rate ◽  
Corrosion Inhibitor ◽  
Economic Efficiency ◽  
Concentration Ratio ◽  
Scale Inhibitor ◽  
Circulating Water

According to the requirements of the circulating water treatment, a corrosion and scale inhibitor which compounded several single corrosion inhibitor and scale inhibitor was prepared, resulting in simplifying the process of operation, improving the concentration ratio of circulating water from 2.2 to 2.8, reducing the sewage volume, and decreasing the corrosion rate and cohesion rate. Therefore, the economic efficiency of the power plant gets greatly improved.

Pre-Treatment Experimental Study of Organic Acid: An Alternative Means to Overcome Inorganic Scale Build-Up Problem in Deep Well

2021 ◽  
Author(s):  
Bagus Muliadi Nasution ◽  
Andrew Yonathan ◽  
Muthi Abdillah ◽  
Wang Zhen
Keyword(s):  
Hydrochloric Acid ◽  
Formic Acid ◽  
Organic Acid ◽  
Corrosion Inhibitor ◽  
Corrosion Test ◽  
Oil And Gas ◽  
Experimental Studies ◽  
Oil And Gas Industry ◽  
Scale Inhibitor ◽  
Pre Treatment

Abstract Organic acid has been widely applied for inorganic scale treatment in oil and gas industry including well stimulation and scale inhibitor. Thanks to its low corrosivity and slower reaction rate with rock, organic acid is considered to offer better performance comparing to strong acid - Hydrochloric Acid (HCl). Yet, proper treatment requires vigorous analysis and experiment in order to meet foremost expectations. Besides, mistreatment of scale could result in formation damage including clay precipitation. Pre-treatment experiments were performed on Zelda field at South East Sumatera block, that has faced with scale problem for ages. Water sample was taken from flowing Zelda A-08 well to be analyzed for mineral's saturation level. Scale was extracted from three sources including tubing, sand bailer, and Electrical Submersible Pump (ESP) of Zelda A-08. Those scale were treated in X-Ray Powder Diffraction (XRD) for mineral composition, and solubility test that utilized two types of acid system - formic acid (HCOOH) and hydrochloric acid (HCl) for comparison. Anti-swelling test and corrosion test were performed to examine the effectiveness of clay stabilizer and corrosion inhibitor. As for carbonate analysis, both formic acid 9% and HCl 15% have comparable solubility (98.17% vs 98% for tubing's scale, 91.86% vs 82.79% for ESP's scale, and 70.30% vs 68.07% for sand bailer's scale). Yet, longer reaction is carried out by formic acid 9% (1 hour) comparing to HCl 15% (18 minutes). For silicate analysis, HF-formic acid provided the higher solubility than HF-HCl (8.34% vs 5.67% for ESP's scale and 30.48% vs 25.68% for sand bailer's scale). On anti-swelling test, by reducing swelling tendency up to 62.6%, it proves that examined clay stabilizer works perfectly against swelling potential of clay, despite of high swelling tendency of sand bailer's scale (25.8%). On corrosion test, adding on corrosion inhibitor (pyridine-based) into solution results in regular HCl 15% has corrosion rate 26.279 g/m2.h which is much higher (300%) than HF-HCl (7.977 g/m2.h) and HF-formic acid (8.229 g/m2.h). Based on pre-treatment test, formic acid 9% together with examined corrosion inhibitor and clay stabilizer, can be used as an alternative to regular HCl 15% for stimulation purpose where more areas will be covered that previously left unreachable by regular acid 15%. In addition, potentially more effective squeezed scale inhibitor using organic acid can also be achieved by performing further experiments. The method presented in this paper for pre-treatment experimental studies of organic acid can provide engineers with intensive guide to meet the best result of organic acid treatment.

Iron Sulfide Inhibition: Field Application of an Innovative Polymeric Chemical

2015 ◽  
Author(s):  
Jonathan J. Wylde ◽  
Cyril Okocha ◽  
Matthew Bluth ◽  
Adam Savin ◽  
Ben Adamson
Keyword(s):  
Iron Sulfide ◽  
Field Application ◽  
Sulfide Inhibition

Development of a Novel Iron Sulfide Scale Inhibitor for Onshore US Application

2019 ◽  
Author(s):  
Narayan Bhandari ◽  
Manoj Bhandari ◽  
Ian Littlehales ◽  
Julie Fidoe
Keyword(s):  
Iron Sulfide ◽  
Scale Inhibitor

Iron Sulfide and Zinc Sulfide Inhibition and Scale Inhibitor Consumption

2019 ◽  
Author(s):  
Bader Alharbi ◽  
Norah Aljeaban ◽  
Alexander Graham ◽  
Kenneth S. Sorbie
Keyword(s):  
Zinc Sulfide ◽  
Iron Sulfide ◽  
Scale Inhibitor ◽  
Sulfide Inhibition

The Field Application of a Scale Inhibitor Squeeze Enhancing Additive

1997 ◽  
Author(s):  
I.R. Collins ◽  
L.G. Cowie ◽  
M. Nicol ◽  
N.J. Stewart
Keyword(s):  
Field Application ◽  
Scale Inhibitor

Study on Corrosion Scale Inhibitor for Blast Furnace Gas TRT System

2013 ◽  
Vol 864-867 ◽  
pp. 1342-1345
Author(s):  
Fu Rong Zhou ◽  
Hu Zhang ◽  
Guang Wu Du ◽  
Wen Hua Wang
Keyword(s):  
Weight Loss ◽  
Blast Furnace ◽  
Corrosion Inhibitor ◽  
Inhibition Efficiency ◽  
Acid Anhydride ◽  
Scale Inhibitor ◽  
Corrosion Scale ◽  
Blast Furnace Gas ◽  
Weight Loss Method ◽  
Loss Method

Cyclohexylamine, morphine, ethanolamine, propiolic alcohol, seventeen alkenyl amide ethyl imidazoline, water depolymerization malaya acid anhydride, etc were chosen as the raw material of corrosion scale inhibitor in view of corrosion scaling reason and characteristic of blast furnace top gas pressure recovery turbine unit. The optimized formula of corrosion inhibitor have been obtained through orthogonal experiment. Corrosion and scale inhibitor performance were evaluated respectively by static weight-loss method, dynamic weight-loss method and calcium carbonate deposition. The results show that when these components are reasonable distributed, the corrosion effect is satisfied. When water depolymerization malaya acid anhydride is combined with the corrosion inhibitor, the corrosion and scale inhibition efficiency of composite inhibitor are more than 90%. Simulation blast furnace gas is adopted in dynamic simulation experiment, the corrosion inhibition efficiency is over 92%.

A Game Changer in Scale-Squeeze Technology

2021 ◽  
Vol 73 (02) ◽  
pp. 40-43
Author(s):  
Paula Guraieb ◽  
Ross Tomson ◽  
Victoria Brooks ◽  
Ji-young Lee ◽  
Jay Weatherman
Keyword(s):  
Field Trials ◽  
Field Application ◽  
Third Party ◽  
Reservoir Rock ◽  
Formation Damage ◽  
Scale Inhibitor ◽  
No Formation ◽  
Intact Core ◽  
Large Improvement

Background Field trials using a new scale-inhibitor technology that improves treatment lifetime of scale squeezes have been successfully performed in the Gulf of Mexico. Tomson Technologies, in partnership with Shell, developed proprietary nanoparticle carriers that enhance scale-inhibitor adsorption to the reservoir and control the return rate for extended periods of time. This technology results in less chemical bleed off in the initial flowback and increases the chemical retained in the reservoir, allowing for more effective squeeze treatments. Both nanoparticle-enabled phosphonate and polymer inhibitors have now been developed and successfully squeezed in the field. Phosphonate inhibitors are widely used for squeeze treatment due to their desirable adsorption and release properties in carbonate and sandstone reservoirs. Minor changes have been made to the chemistry, but overall, the fundamentals have remained unchanged for decades. Polymeric scale inhibitors have also been developed for cases in which phosphonates are not applicable. The nano-enhanced technology provides a large improvement of treatment lifetime of 2 to 4 times (200-400%) when compared to incumbents, making this technology advancement attractive even in cases where current squeezes are considered successful. The well selected for this case study is an offshore formation with a predominantly sandstone mineralogy (approximately 80% quartz) with 25-30% porosity and bottomhole temperature of 183°F (83°C). Technology From the Lab to Field A sandpack sample from the trial well was used in the laboratory to deter-mine the adsorption and desorption properties of the nano-enabled inhibitor in realistic rock conditions. Multiple conditioning steps were used before product was injected in a sequence that mimicked field squeeze treatments. Mass-balance results from the sandpack experiment show adsorption of approximately 8 mg of polymer retained per gram of crushed reservoir rock used in the experiment. A typical rule of thumb for phosphonate-scale inhibitors (only as a comparison since this is a polymeric scale inhibitor) is 1-2 mg of inhibitor retained per gram of rock. Therefore, this is considered a large improvement on adsorption. There are challenges associated with measuring polymers in brine as residuals; however, multiple methods, both in-house and external, were com-pared to ensure accuracy. The results using the nano-enhanced scale inhibitor show concentrations higher than 1 mg/L of active polymer for over 7,000 pore volume of return in the sandpack experiment. Complete intact core experiments were also conducted with reservoir fluids and showed no formation damage during the injection of the product with regained oil permeability of 96%. Oil permeability was in the 150-200 mD range for the intact core experiments. Third-party coreflood testing was performed with nitrified and foamed stages to ensure compatibility with the nano-enabled chemistry. No formation damage was observed with the nitrification of the stages containing the nano-enabled chemistry. Field Application Case Study After extensive lab validation of the product and supporting corefloods to de-risk the technology, Well A was selected by Shell to be the first well treated with the new nano-enabled extended-lifetime inhibitor.

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