For decades, fixed-rate chemical application programs have been applied to oilfield fluids with fluctuating chemistries. This approach leads to inefficient chemical dosing and asset management schemes, which impact well production and equipment longevity. Leveraging advances in technology, and through the integration of proprietary software/hardware offerings, the ReStream Solutions Fluid monitoring package provides operators with real-time, on-site fluid chemistry and dynamics monitoring, and automates the chemical application process.
ReStream systems utilize cloud-based data management and analysis tools to monitor assets at a local, geographic and reservoir level. The real-time acquisition and evaluation of this data allows ReStream systems to continuously maximize system efficiency and profitability.
ReStream systems feature on-board cell modem and SATCOM communication capability. All data collected by the systems is continuously streamed to ReStream servers where it is further analyzed and used to provide customers with customized user interfaces into their operations.
ReStream systems monitor fluid chemistries and dynamics in real-time, identify potentially problematic conditions within the fluid, and automatically apply the necessary chemistry required to address those problems.
ReStream systems are built to operate in the harshest oilfield environments and monitor highly contaminated oilfield fluids reliably. ReStream systems can be deployed in Class 1 Div 2, Class 1 Div 1 environments, and can operate in high pressure environments.
The ReStream Production Monitoring Platform’s innovative approach to production monitoring, management, and chemical treatment application will help your company increase well productivity and maintain production equipment and hardware.
ReStream Fluid Monitoring at Work
Management of drilling, frac, completion, flowback, and production chemistries, flow assurance, and well monitoring
Identification of when and where problematic conditions exist as various fluids are pushed into pipeline and comingled
Monitors drilling fluids, frac fluids and production fluids for real-time data acquisition and control
Identifies the source and type of oilfield chemistry problems
Monitors well performance, evaluates chemical treatment effectiveness, and controls corrosion
Integrates into existing downstream facilities to optimize process efficiencies
Fluid Fingerprinting Software
Production Fluid Monitoring
Fluid fingerprinting is what allows ReStream to accurately characterize fluid properties and mitigate potential problems. As fluid chemistries and dynamics are recorded in real-time, the ReStream software package identifies fluid trends and identifies fluid response to chemical application regimes. The production chemistry values and analytic relationships across technologies allow for the fingerprinting of down-hole and pipeline conditions. This fingerprinting allows for the establishment of baseline conditions, and identification of changes resulting from different applied stimuli.
ReStream’s proprietary suite of analytical sensors applies composite metric analysis in order to help track and protect against:
The loss of metal due to chemical or electrochemical reactions, which could eventually destroy a structure. Corrosion can occur anywhere in the production system, either at bottom hole or in surface lines and equipment. The corrosion rate will vary with time depending on the particular conditions of the oil field, such as the amount of water produced, secondary recovery operations and pressure variations.
An extraordinarily poisonous gas with a molecular formula of H2S. At low concentrations, H2S has the odor of rotten eggs, but at higher, lethal concentrations, it is odorless. H2S is hazardous to workers and a few seconds of exposure at relatively low concentrations can be lethal, but exposure to lower concentrations can also be harmful. H2S can cause sulfide-stress-corrosion cracking of metals. Because it is corrosive, H2S production may require costly special production equipment such as stainless steel tubing. Sulfides can be precipitated harmlessly from water muds or oil muds by treatments with the proper sulfide scavenger.
A common anaerobic bacterium, commonly abbreviated SRB, that can convert sulfate ions, SO4-2, into S-2 and HS-, with the concomitant oxidation of a carbon source. The lignite, lignin, tannins, cellulose, starches and fatty acids found in many mud systems are carbon food sources for SRB. Where mud is stored, precautions should always be taken when handling or reconditioning water muds containing lignosulfonates, gypsum (sulfate sources) and starches, cellulose, xanthan gum and lignite (food sources). These muds can harbor SRB and can have high sulfide accumulations. Mud filtrate should be tested with the Garrett Gas Train to determine sulfide concentration in a stored mud, followed by treatments with caustic soda to raise pH and zinc-based scavengers to remove sulfides as ZnS. Before storage of mud, treatment with a bactericide can inhibit SRB growth. Also, circulating mud from time to time, with air entrainment, can retard development of anaerobic conditions. Anaerobic bacteria can convert the sulfate or sulfite present in water handling facilities to hydrogen sulfide [H2S]. This by-product, combined with iron, can form iron sulfide, a scale that is very difficult to remove. SRB occur naturally in surface waters, including seawater. Bacteria accumulation can lead to pitting of steel, and the buildup of H2S increases the corrosiveness of the water, thus increasing the possibility of hydrogen blistering or sulfide stress cracking.
A mineral salt deposit that may occur on wellbore tubulars and components as the saturation of produced water is affected by changing temperature andpressure conditions in the production conduit. In severe conditions, scale creates a significant restriction, or even a plug, in the production tubing. Scale removal is a common well-intervention operation, with a wide range of mechanical, chemical and scale inhibitor treatment options available.
A hydrocarbon compound that often precipitates on production components as a result of the changing temperatures and pressures within the production system. Heavy paraffins occur as wax-like substances that may build up on the completion components and may, if severe, restrict production. Paraffin is normally found in the tubing close to surface. Nevertheless, it can form at the perforations, or even inside the formation, especially in depleted reservoirs or reservoirs under gas-cycling conditions.