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Results
Abstract Deoiling hydrocyclones are a mature technology for oil removal from produced water. Since the introduction of this technology in the 1980s it has become ubiquitous in all oil producing regions. From its original intent – to treat water directly off the outlet leg of a production separator – many operators have tried to use deoilers for every water treating application. The lack understanding the operation and design of deoilers has led to misconceptions around their performance. Deoiling hydrocyclones can treat emulsions, high-pressure gas condensate water, high-turndown requirements, and work with pumps – however their fundamentals must still be adhered to for the system to work properly. Not all deoiler liners are the same and vendor experience is critical during evaluation of this technology.
- Water & Waste Management > Water Management > Lifecycle > Treatment (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Oceania > Australia (0.89)
- Europe > Russia > Northwestern Federal District > Komi Republic > Timan-Pechora Basin > Pechora-Kolva Basin > Usa Field (0.89)
Abstract Produced water is naturally occurring water that is produced as a byproduct during the exploration and production of oil and natural gas from the subsurface system. Produced water brought to the surface contains high saline content and may also contain Naturally Occurring Radioactive Material (NORM). Therefore, the efficient treatment, use, and disposal of produced water remain a critical issue for the energy industry with environmental and human health implications. Over the years, researchers have presented numerous treatment technologies ranging from physical, chemical, and biological perspectives. Some industries have combined one or two of these methods to improve the treatment quality of produced water required for distinct purposes, and these practices have been extended to the energy industry. As the energy industry strives to sustain production capacities and maintain or increase profitability in this energy-transition era, water production is also rising while there is a reduction in its re-purposing and utilization for energy and environmental industries. Our study focuses on over 100 studies conducted over the past five decades. This study presents a comprehensive overview of the produced treatment methods, challenges regarding the execution and implementation of these methods in the energy industry. We highlight the important fundamental questions that are yet to be addressed and propose new directions for more environmentally friendly and economically viable solutions for the treatment and use of produced water.
- North America > United States (1.00)
- Asia (1.00)
- Water & Waste Management > Water Management > Lifecycle > Treatment (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.99)
- (8 more...)
Abstract For many years, reverse osmosis (RO) elements have been used in the treatment of produced water, including at several sites in California. The RO reduces salts and organics in the produced water to a level that allows for disposal or reuse. The RO elements used to treat produced water are similar in chemistry and construction to the conventional seawater RO membrane. But compared to seawater, the characteristics of produce water are unique and varied. The conventional seawater membrane comes with pressure and temperature limitations that restrict its ability to treat a wide range of produced waters. Specifically, conventional membranes have a temperature limit and a pressure limit. Only a portion of the produce waters needing treatment fall within the membrane's temperature and pressure limitations. Many produced waters, including produce waters associated with SAGD, require membranes that can accommodate higher temperatures up to 60 C. Other produced waters may allow for treatment at ambient temperatures but their higher salinities above 60,000 mg/l TDS require RO membrane to overcome high osmotic pressures and operate at feed pressures up to 1800 psi. In recent years, membrane manufacturers have enhanced their exiting RO elements to address the challenges associated with the treatment of unique industrial streams such as produced water. Specifically, new, more robust element construction allow designers to push beyond the normal limits of temperature and pressure. One such element allows for operation at temperatures up to 90 C while a second, ultra high-pressure RO (UHPRO), can concentrate the total dissolved salts (TDS) up to 120,000 ppm (12%) while operating at pressures up to 1,800 psi (124 bar). These unique elements can be used to increase the overall efficiency of the treatment facility by reducing the cost of brine disposal and maximizing water recovery. This paper will show how these new elements perform when operated beyond conventional pressure and temperature limits - including how individual ion passage and water permeability are affected at extreme conditions. This paper will share element performance data from laboratory and pilot studies. The data will be used as a basis for new designs at the extreme conditions associated with produced water treatment.
- North America > United States > California (0.35)
- North America > United States > Florida (0.28)
- Water & Waste Management > Water Management > Lifecycle > Treatment (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Abstract Seawater injection is widely used to maintain the offshore oil reservoir pressure and improve oil recovery. However, injecting seawater into reservoirs can cause many issues such as reservoir souring and scaling, which are tightly related to the seawater breakthrough percentage. Accurately calculating the seawater breakthrough percentage is important for estimating the severity of those problems and further developing corresponding strategies to solve those issues. The validation of using natural ion boron as tracer to calculate seawater breakthrough percentage was investigated. Boron can interact with clays, which can influence the accuracy in seawater breakthrough calculation using boron. Therefore, the interaction between boron and different clays at various conditions were studied, and Freundlich adsorption equation was used to describe the boron adsorption isotherms. Then boron adsorption isotherms were coupled into the reservoir simulator to investigate the boron transportation in porous media, and the results in turn were further analyzed to calculate the accurate seawater breakthrough percentage. Results indicated that boron adsorption by different clays varied. pH value of solution can significantly influence the amount of boron adsorbed. As a result, the boron concentration profile was delayed in coreflood test. The results of reservoir model fit perfectly with that of coreflood test, indicating the validation of boron reaction model. Based on the reservoir simulator results, boron concentration profile in produced water was successfully used to calculate seawater breakthrough percentage by considering the clay content distribution. However, the seawater breakthrough point cannot be calculated by boron as boron concentration is still at the formation level due to boron desorption.
- Research Report > New Finding (0.64)
- Research Report > Experimental Study (0.40)
Abstract This paper presents the results of a successful field trial using electrocoagulation and reverse osmosis to desalinate oilfield produced water for surface discharge and beneficial reuse near Bakersfield, California. The paper discusses technology selection, pilot test configuration, test results, projected operating costs and reliability, and conclusions. The field trial was conducted at an oilfield wastewater facility where up to 10,000 barrels per day of produced water containing 3,700 mg/L of TDS (total dissolved solids) was being treated in a series of un-lined ponding basins to remove free oil and solids, and then used to irrigate an area containing salt-tolerant grasses, shrubs, and trees. Due to concerns that local groundwater might be impacted, in 2016 the operator was given two years by regulators to substantially reduce the salt, aromatic hydrocarbon, and boron content of the water, or cease surface discharge. After a detailed review of options, the operator elected to conduct a 60-day pilot test of a process that consisted primarily of electrocoagulation followed by reverse osmosis to desalinate the produced water and remove aromatic hydrocarbons. Boron removal would be accomplished by use of a boron-specific anion exchange resin downstream of the reverse osmosis membranes. The pilot treatment system would be designed and installed to comply with the local Regional Water Quality Control Board specifications for surface discharge, herein collectively called the "Effluent Specifications" (Table 1). In July 2016, the operator started the 60-day pilot test. After an initial commissioning period, the facility demonstrated the ability to safely and reliably treat the produced water to below the limits contained in the Effluent Specifications.
- Water & Waste Management > Water Management > Lifecycle > Treatment (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Potential Use of Oil-Field Produced Water as Base Fluid for Hydraulic Fracturing Operations: Effect of Water Chemistry on Crosslinking and Breaking Behaviors of Guar Gum-Based Fracturing Fluid Formulations
Saini, Dayanand (Department of Physics and Engineering, California State University) | Mezei, Timea (Department of Physics and Engineering, California State University)
Abstract Though, only few hundreds of hydraulic fracturing jobs are carried out in California, however, the use of oilfield-produced water resulting from conventional oil production operations for preparing fracturing fluid formulations appears a great alternative for unlocking the potential of Monterey shale without putting burden on precious fresh water resources of the region. The present experimental study reports on the crosslinking and breaking behaviors of guar-gum based fracturing fluids formulations prepared using synthetic but representative oil-field produced water samples. The results suggest that the base fluid composition had little effect on the crosslinking behavior when crosslinked formulations were subjected to high shear rate. On other hand, breaking behavior of the studied fracturing fluid formations was affected by the guar gum concentration used for preparing the formulations. The efficacy of a commercially available bio-degradable breaker in breaking in cross-linked formulations was also evaluated at elevated temperature up to 185°F. The crosslinking and breaking behaviors of fracturing fluid formulations prepared using oil-field produced water as base fluids were comparable to the behaviors of typical fracturing fluid formations prepared using 2% potassium chloride solution as base fluid. The results of this study are encouraging as conventional oil and gas production operations in California can provide an alternative source of water for base fluid to use in hydraulic fracturing based exploitation of Monterey shale resource in near future. Use of sea water for preparing fracturing fluid formulations for offshore applications will also help in reducing the need of treated sea water for any futre growth of hydraulic facturing technology in offshore environment. It is noted here that the paper is a derivative work of the original paper first published in the Energy and Environment Research Journal (Vol. 6, No. 1; June 2016).
- Research Report > New Finding (0.89)
- Research Report > Experimental Study (0.55)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.45)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play > Shale Oil Play (0.45)
Abstract Low-salinity waterflooding has proven to be an appealing technique for enhancing oil recovery in conventional reservoirs. However, few studies have been conducted on low-salinity brines (LSBs) for hydraulic fracturing in liquids-rich shale plays with or without surfactant. Additionally, as operators tend to shift from fresh water to 100% produced water, the implications of such a switch must be understood from a production standpoint. Therefore, the effects of LSBs on oil recovery from liquids-rich shale should be investigated. In this study, LSBs with or without surfactant were injected into the crushed, oil saturated Muskwa shale from Canada. Laboratory results suggest that LSB (≤4% KCl) extracts more hydrocarbon than high salinity brine (HSB) (≥8% KCl). Notably, additional oil recovery was observed when surfactant was used in LSB. Interfacial tension (IFT) reduction decreased with increasing salinity but remained constant for LSB with surfactants across all salinities examined. Short-lived oil in water emulsions were observed in LSB in the presence of surfactant. Additionally, LSBs with surfactant were injected into a microfluidic based reservoir on a chip (ROC) device, where pore size was comparable to that of shale. The visualized oil recovery on the ROC was consistent with that found in core flooding tests. These reported results provide a potential methodology for optimizing source water before hydraulic fracturing operations. LSBs with properly tailored surfactant additives are imperative to helping enhance well productivity.
- North America > Canada (0.72)
- North America > United States > California > Orange County (0.29)
Abstract Large volumes of saline water are produced during unconventional oil and gas development, and the water can rarely be reinjected into the same formation from which it was extracted. This water, known as produced water, can provide a valuable additional water source to local communities. For example, in Australia, South America, and the arid western United States, reusing produced water decreases demand on potable water supplies and aids in helping oil and gas operators achieve a social license to operate. However, produced water is currently regulated as a waste in almost all jurisdictions, limiting its beneficial reuse. Our team has developed a reproducible framework to create comprehensive Produced Water Management Plans that provide operators with a large suite of options to beneficially reuse produced water. The framework consists of the following four steps: (1) Analyze the produced water source; (2) Understand the needs of local water users; (3) Compare the compatibility between the produced water quality and the water quality objectives of target end reuses; and (4) Determine the appropriate options for treatment if necessary. Once the plan is developed, the permitting and approval path is designed and implemented. Examples of beneficial reuse options span from recycling for field use including well stimulation, to crop irrigation, industrial washwater, golf course irrigation, wildlife habitat support, and livestock watering. While the framework for developing management plans is widely applicable, the beneficial uses recommended within the plans are intensely site-specific due to local regulatory settings, reuse options available in the vicinity, and the chemical properties of the produced water. In California, the development of a Produced Water Management Plan led to a suite of reuse options including field water use, creek discharge to support critical wildlife habitat, and irrigation for local wineries. The latter two options required treatment. In Australia, the Produced Water Management Plan recommended livestock watering and industrial use with untreated water or irrigation for growth of fodder plants with treated water. These results demonstrate that beneficial reuse of produced water can gain regulatory approval and local acceptance. In times of water scarcity, wisely managing water resources becomes more important. As regulatory hurdles ease, there should be more opportunities for the beneficial reuse of produced water.
- Water & Waste Management > Water Management (1.00)
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Pennsylvania > Appalachian Basin > Marcellus Shale Formation (0.99)
- (4 more...)
Abstract Production optimization for offshore oil and gas production is in general a challenging task due to the many and potentially conflicting control objectives that arise from the intrinsic complexity of the domain. Therefore the development of control system software that can accommodate the required changes to the control logic as oil fields mature is equally challenging. In this paper we present a novel multi-agent software approach that facilitates intelligent stratified multi-objective control. In offshore control systems of today implementations of individual control concerns are scattered across software components of the control systems. Hence, modification of a control concern requires full inspection of the software components to ensure that the change does not conflict with any of the other control concerns. This results in relatively fixed control schemes, as changes to the control system is very expensive and time-consuming. The intrinsic tangling of control concerns is especially a problem when introducing new control concerns or production configurations, which could not be foreseen in the initial design phase. At the DONG E&P operated Siri area, which we use as test case, several optimization studies have shown that an increase in production throughput is possible, if a more flexible approach to control were in place. The approach that we propose uses advanced multi-agent software technologies to divide the concerns of the control system into independent control modules implemented as software agents. Our approach provides improved flexibility allowing inclusion, replacement and upgrades of both control strategies and equipment, as dynamic properties of the installation and reservoirs are described in software, and interactions between independent modules are automatically handled by intelligent negotiation mechanisms. We demonstrate in this paper that it is possible to have intelligent multi-objective control with a better performance than operator-based control, even at fields with complex configurations.
- North America > United States (1.00)
- Europe > Denmark (0.69)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Abstract This paper is about an HPHT subsea tieback to a gas-condensate platform. Gas and fluids from three wells are routed through individual in-field flow lines and gather at a subsea manifold several miles from the platform. The fluids pass from the manifold through a pipe-in-pipe pipeline back to the platform. Industrial methylated spirit (IMS) was the hydrate control chemical selected for the tieback and was used to inhibit the pipeline on a "cold start" after depressurization. There was very little data on the phase-partitioning of IMS, and quantities could end up at the oil terminal where they have a serious effect on processing and product quality. This paper summarizes the management of using large quantities of IMS (30 m) to cold start this subsea field. Results from a series of injection trials at the oil terminal have been summarized and show how partitioning of IMS occurs. Further, the paper explains how this proved crucial in risk assessing the impact and use of IMS on the platform. The data has been used to improve the model (CPA equation of state and HYSYS) data sets and details of this have also been included. Extensive sampling exercises performed offshore, when injecting and processing IMS (necessary in order to meet export waiver requirements), are added and lead to details of phase-partitioning behavior through the platform process plant. Such considerations are rarely made, nor lengths taken to understand the exact partitioning and fate of a chemical when injected offshore, as well as arrival at the terminal. The implications in this instance were significant and therefore the exercise was necessary. The results show that exact quantification is very elusive and that relying on models and standard principles can be misleading and potentially damaging.
- Research Report > New Finding (0.34)
- Research Report > Experimental Study (0.34)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.36)