Water to Value – Produced Water Management for Sustainable Field Development of Mature and Green Fields

Khatib, Z.I.; Verbeek, Paul

doi:10.2118/73853-ms

Cited by 62 publications

(37 citation statements)

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“…The global water cut has risen since a decade ago and continues to rise. Produced water is driven up by maturing of old fields but driven down by better management methods and the introduction of new oil fields [7,8]. Fig.…”

Section: Global Onshore and Offshore Produced Water Productionmentioning

confidence: 99%

Review of technologies for oil and gas produced water treatment

Fakhru’l‐Razi

Pendashteh

Abdullah

et al. 2009

Journal of Hazardous Materials

1,865

787

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Produced water is the largest waste stream generated in oil and gas industries. It is a mixture of different organic and inorganic compounds. Due to the increasing volume of waste all over the world in the current decade, the outcome and effect of discharging produced water on the environment has lately become a significant issue of environmental concern. Produced water is conventionally treated through different physical, chemical, and biological methods. In offshore platforms because of space constraints, compact physical and chemical systems are used. However, current technologies cannot remove small-suspended oil particles and dissolved elements. Besides, many chemical treatments, whose initial and/or running cost are high and produce hazardous sludge. In onshore facilities, biological pretreatment of oily wastewater can be a cost-effective and environmental friendly method. As high salt concentration and variations of influent characteristics have direct influence on the turbidity of the effluent, it is appropriate to incorporate a physical treatment, e.g., membrane to refine the final effluent. For these reasons, major research efforts in the future could focus on the optimization of current technologies and use of combined physico-chemical and/or biological treatment of produced water in order to comply with reuse and discharge limits.

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Section: Global Onshore and Offshore Produced Water Productionmentioning

confidence: 99%

Review of technologies for oil and gas produced water treatment

Fakhru’l‐Razi

Pendashteh

Abdullah

et al. 2009

Journal of Hazardous Materials

1,865

787

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“…These factors make crude oil emulsions a significant economic problem, which will only become more pronounced as oil fields age and more deep water fields are produced. 4 A variety of methods are used to break crude oil emulsions, including the use of de-emulsifiers, electrostatics, heat treatment, and gravity (e.g., centrifugation). 5 To effectively implement these methods, knowledge is required of microstructural changes occurring in the emulsion, with temporal changes in droplet size distribution (DSD) being particularly important.…”

Section: ■ Introductionmentioning

confidence: 99%

Optimized Droplet Sizing of Water-in-Crude Oil Emulsions Using Nuclear Magnetic Resonance

et al. 2014

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Water-in-crude oil emulsions are an increasing problem during production. Essential to any emulsion breaking method is an ability to accurately measure droplet size distributions; this is rendered extremely difficult given that the samples are both concentrated and opaque. Here, we systematically consider the use of a standard, low-field benchtop nuclear magnetic resonance (NMR) apparatus to accurately measure the droplet size distributions. Such measurements are challenging because the NMR signal from the oil phase erroneously contributes to the measured water droplet size distribution. Conventionally, the oilphase signal is nulled-out based on differences in the NMR T 1 relaxation parameter between water and oil. However, in the case of crude oil, the oil presents a broad T 1 distribution, rendering this approach infeasible. On the basis of this oil T 1 distribution, we present an optimization routine that adjusts various NMR measurement timing parameters [observation time (Δ) and inversion time (T inv )] to effectively eliminate this erroneous crude oil contribution. An implementation of this optimization routine was validated against measurements performed using unambiguous chemical-shift selection of the water (droplet) signal, as would conventionally be provided by high-field superconducting NMR spectrometers. We finally demonstrate successful droplet sizing of a range of water-in-crude oil emulsions.

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“…The fracture length is calculated assuming: σ = tip wf P (1) In this fracturing criterion, the flowing pressure is considered constant along the fracture length. When the fracturing criterion is satisfied, the program proceeds by successive iteration (dichotomy method) to find the half length X f of the fracture which satisfies this equilibrium between the fluid mechanics and rock mechanics given by (1).…”

Section: Tif Model For Clean and Cooled Watersmentioning

confidence: 99%

“…When the fracturing criterion is satisfied, the program proceeds by successive iteration (dichotomy method) to find the half length X f of the fracture which satisfies this equilibrium between the fluid mechanics and rock mechanics given by (1).…”

Section: Tif Model For Clean and Cooled Watersmentioning

confidence: 99%

“…Today produced water management would be assessed as part of the integrated reservoir management and considered as strategic to the sustainable oilfield development 1 . Regarding the increasing amount of produced water in mature fields, their re-injection in reservoir becomes very attractive because of the more and more constraining environmental regulations and the increasing treatment coasts.…”

Section: Introductionmentioning

confidence: 99%

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A Simulator For Produced Water Reinjection in Thermally Fractured Wells

Detienne

Ochi

Rivet

2005

SPE European Formation Damage Conference

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe objective of the analytical simulator presented here is to predict the opposite and complex effects induced by the injected produced water temperature and formation damage on thermally fractured wells. The deposition of solid particles and oil droplets in a fracture and its effect on the Injectivity Index evolution of an injector is then simulated. The principle is to inject cooled waters like sea water for example during a certain period of time to enable the well to develop a thermal fracture. When the fracture is well established, the re-injection of hot produced waters starts. The model takes into account the effect of this new water temperature on the viscous flow and on the fracture shrinkage and closure. In the same time oil droplets and solid particles contained in produced water cause the damage of the reservoir. This tends to open and propagate the fracture under bottom pressure increase. In the simulator, the internal formation damage and the external filter cake deposition in the fracture occur simultaneously. Two internal formation damage deposition models are taken into account. In a first model the internal damage is supposed to be linear and occurring from the fracture faces to the reservoir. In a second model, despite the growth of the fracture, the internal damage is supposed to be radial and occurring from the wall of the well to the reservoir. Also, two exeternal filter cake deposition models are considered: the filter cake deposits only at the fracture tip or on fracture faces. Theoretical field cases were considered in the simulations. The different internal formation damage and filter cake models were combined together to reproduce the injectivity index evolution observed on real fileds. The example presented are chosen to show that, contrarily to common thinkings, the II evolution can be dominated, in certain circumstances, by the internal damage rather then by the external filter cake deposition. With the present choice of data, the II evolution which matches better the commonly observed field reponses is obtained when the internal damage occurs in radial flow whatever the model deposition of the external filter cake is.

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Water to Value – Produced Water Management for Sustainable Field Development of Mature and Green Fields

Abstract: TX 75083-3836, U.S.A., fax 01-972-952-9435. Abstract Produced Water Volumes

Cited by 62 publications

References 0 publications

Review of technologies for oil and gas produced water treatment

Review of technologies for oil and gas produced water treatment

Optimized Droplet Sizing of Water-in-Crude Oil Emulsions Using Nuclear Magnetic Resonance

A Simulator For Produced Water Reinjection in Thermally Fractured Wells

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