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In this paper the charging procedure will be demonstrated. Two case histories will be shown including autoclave telemetry data (pressure and temperature) and pressure measurements taken at temperature.
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Results from novel transparent autoclave experiments. Carbon steel corrosion coupons were exposed to impurities levels within established specifications at simulated transport conditions (25 °C and 10 MPa of CO2).
Laboratory testing on two candidate completion brines…a buffered mixed formate and a proprietary bromide brine. Materials tested: super martensitic stainless, super duplex stainless, API 5CT/ ISO 11960 grade “C125” casing and nickel alloy.
Titanium does not show the required mechanical strength for high temperature high pressure applications and it can only be used to form liners for an SCWO apparatus. Therefore, pressure tubes made of alloy 625 were lined with titanium grade 2, Additionally corrosion tests with coupons made of titanium grades 2, 5, 7, 12 and P-C were performed.
The crude oil produced by fracking or hydraulic fracturing method are high in sulfur content (0.5%)1. The vast majority of vessels that are used in the petrochemical industry to store and transport materials are constructed using Carbon steel. Coating linings used for corrosion protection inside of vessels and tanks must perform under severe conditions such as an exposure to corrosive gasses ( H2S) and carbon dioxide as well as high temperatures, high pressures and often must withstand the cold wall effect and rapid decompression.
To maintain production levels, oil fields in the Middle East increasingly require water injection to maintain pressure in hydrocarbon reservoirs. The injected water increases the water cut of the produced fluids, resulting in a very corrosive mixture for metallic piping. Therefore, nonmetallic pipe systems have become more widely accepted as alternative pipe materials for transporting produced fluids and injection water.
High pressure (HP) and ultra-high pressure (UHP) waterjetting for coating removal and surface preparation has several advantages compared to the industry standard abrasive grit blasting process. However, a major drawback of waterjetting is subsequent flash rusting of the steel surface. The color of the flash rust is typically orange, red, or brown of various shades depending on the color of the underlying steel, the nature of the surrounding environment, and the duration of exposure to the environment.
Laboratory testing of corrosion inhibitors under high temperature high pressure (HTHP) conditions is challenging. HTHP testing has been traditionally performed in closed systems with fixed liquid/gas volume and testing results are usually influenced/compromised by the accumulation of ferrous ions and corrosion products. The aim of the work is to optimize corrosion inhibitor testing conditions at HTHP to generate results of better reliability. The corrosion of carbon steel by CO2 at HTHP was assessed using small working electrodes of large liquid volume-to-sample surface area in autoclaves. The effect of CO2 partial pressure was also investigated. The blank and inhibited corrosion rates were monitored by linear polarization resistance (LPR) and the morphology of coupon surface was measured by vertical scanning interferometry (VSI). The testing results were deemed to be more representative of the field service environment when the amount of ferrous ions and corrosion products was reduced due to the usage of small working electrodes.
Almost 20 years ago the use of Ultra High Pressure Waterjetting (UHP) in shipyards for maintenance and for offshore projects started to be pushed, due to the development of surface and moisture tolerant paint technology becoming available. This was recognized by the likes of US Navy and Petrobras at the time.
The increasing need for fossil fuels has resulted in more aggressive drilling and exploitation in oil and gas production industry. As new explorations at more extreme conditions (i.e. high temperature and high pressure) become more frequent, new challenges arise in terms of drilling equipment, operation conditions and safe production. Among those challenges, the mineral scale deposition, as one of the serious problems both for the surface and subsurface oilfields, can cause pipelines plugging, equipment failure and decrease in production efficiency, even emergency shutdown.