Waste Engine Oils: Rerefining and Energy Recovery free download


The importance of oil as a lubricating agent for mechanical parts in motion is well known. Adding oil into the engine of a vehicle and noticing that it turns black upon use is a common phenomenon witnessed by all vehicle owners. Indeed, we know that the life cycle of oil is not infinite even if the efficiency of additives is regularly improved. Thus, oil becomes an unavoidable waste and its collection and treatment naturally become important issues for discussion. Owing to the rules that have been in existence in France since 1979 as well as to the financial support from the government via ADEME and last but not least, to the increasing civic responsibihty of the people, a collection rate higher than 80 % for all waste oil is achieved today. Two elimination methods or more precisely two valorization methods are then applied: on the one hand, combustion, a form of energy recovery used mainly in cement factories, and on the other, regeneration, a recycling of the raw material. A European directive gives preference to the latter method. In the United States and in Japan, there are no rules that give priority to any particular method of treatment. Whatever the method used locally, the choice ultimately depends on technical and economic criteria, obviously keeping in mind the impact on the environment, which should be minimized at all costs. The subject remains topical and other methods are also examined here, for example, the consideration of a possible participation of oil refiners in a consortium.

The Chemistry of Essential Oils and Artificial Perfumes Vol 1 and 2 free download


The Chemistry of Essential Oils and Artificial Perfumes Vol 1
Author(s):
Ernest J. Parry
Publisher: Scott Greenwood & Son
Date : 1921
Pages : 556
Format : pdf
OCR : N
Quality : Good
Language : English

The Chemistry of Essential Oils and Artificial Perfumes Vol 2

Author(s): Ernest J. Parry
Publisher:
Scott Greenwood & Son
Date :
1922
Pages :
370
Format :
pdf
OCR :
Y
Quality :
Good
Language :
English

Horizontal wells –Underbalanced Equipment

•Specialized equipment is required to run an underbalanced well •Compressors •Mist pumps •Gas separators •Pressure boosters
•Rotating BOP •Closed loop system

Horizontal wells – Underbalanced

Horizontal wells – Underbalanced
•Under balanced drilling can reduce lost circulation, minimize differential sticking, increase drilling rates, and, most importantly, create higher productivity completions because formation damage is minimized. •To maximize benefits, extreme care must be taken to keep drilling and completion operations underbalanced at all times. •The rate of return from wells drilled underbalanced is typically higher. •Techniques for drilling underbalanced include –Lightweight drilling fluids, –Gas injection down the drill pipe, –Gas injection through a parasite string –Foam injection. •Nitrogen is typically used because of its relatively low generation cost, scale control and low potential for downhole fires. •Nitrogen injection down the drill pipe is the most cost effective when electromagnetic measurement-while-drilling (MWD) is used. •Despite added cost and time, parasite injection of nitrogen is the preferred method when electromagnetic MWD is not possible. •Foams are more stable than aerated systems, but they are more costly
Horizontal wells – Underbalanced Mud Systems
•Lightweight Drilling Fluids. –The simplest mechanism to reduce hydrostatic pressure in the wellbore is the use of lightweight drilling fluids, such as fresh water, diesel or lease crude. –The primary problem with this approach is that hydrostatic pressure can not be reduced enough to remain underbalanced in many reservoirs. Gas Injection Down Drillpipe. –With this technique, air or nitrogen is added to the drilling fluid and it is pumped directly down the drill pipe. –Advantages of this technique include: •Hydrostatic advantage gained over entire vertical depth, •Wellbore does not have to be specifically designed for underbalanced condition, •Less gas is required to achieve given pressure compared to parasite injection •Penetration rate may be improved. •Gas Injection Down Drillpipe Cont –Disadvantages of this technique include: •an overbalanced condition may occur if the well is shut down •exotic MWD systems are required. •Gas Injection Via Parasite String. –With this technique, a second pipe is run outside of the intermediate casing. –Advantages of this technique include: •No operational differences, •Constant bottom hole pressure is achieved, and •Standard MWD equipment can be used. –Disadvantages of this technique include: •Additional costs are incurred, •Additional time is required, •Larger diameter surface casing is required. •Foam Versus Two Phase Flow. –A nitrogen foam system is less damaging to water sensitive formations and has been used on a limited basis. –The additional nitrogen requirements to generate stable foam have made this cost prohibitive in most cases. –Aerated systems with gas/liquid ratios varying from 10-to-1 to 50-to-1 are simple and flexible, but pressure control/gas surging can be a problem. –The margin of safety for aerated systems is typically larger than for more stable systems, such as foams. –Foams also exhibit some sensitivity to hydrocarbons, so large inflows of hydrocarbons can destabilize them. –Temperature limits of current foams, about 180°F, restrict the use of foam to depths less than 12,000 ft.

Taking a Kick-Lost Circulation

Horizontal wells –Taking a Kick
•Most horizontal wells are development wells, this means that the reservoir should have already be well understood. –The chances of taking a kick in a horizontal well are reduced –Surge and swab pressures are still a factor •Well control procedures –Well control procedures are identical to vertical wells –Remember only the vertical component of the well will give you hydrostatic pressure –Drill bit should be on bottom when killing the well
Horizontal wells –Lost Circulation
•Lost circulation is treated similar in horizontal well as in vertical wells issues include: –Sensitivity of the formation to LCM material –Difficulty in spotting pills –Chances for differential sticking while dealing with losses are much higher •Curing lost circulation in horizontals –Always pull out to the first available casing string, mix enough LCM to fill the HZ section –Mix LCM as reservoir and hole conditions dictate •Particle size distribution •Fibers •Gunk squeeze

Horizontal wells -Overbalanced

•Most horizontal wells are completed without cementing or perforation –May have slotted liners –Open Hole completion –Gravel Pack completion Horizontal wells – Overbalanced Mud Systems •A horizontal mud system should have the following characteristics: –Formation damage control: •The horizontal mud system should not contain clays or acid-insoluble weight materials which can migrate into the formation and plug pores. •It should be formulated with breakable or acid-soluble viscosifiers, fluid-loss materials and properly sized plugging agents, all of which limit fluid loss to the formation and assure good clean-up. •The filtrate should be formulated to prevent clays in the producing zone from swelling, migrating or plugging the formation. –Formation damage control cont. •The filtrate should be formulated to prevent clays in the producing zone from swelling, migrating or plugging the formation •The filtrate should be compatible with formation fluids so that it will not precipitate mineral scales. •The fluid and filtrate should not change the wetting characteristics of the formation from either water-wet to oil-wet or from oil-wet to water-wet. •The filtrate should not form emulsions with formation fluids and block the formation. –Drillability: •The horizontal mud system should provide good hole-cleaning, lubricity and inhibition. •It should minimize hole enlargement and provide wellbore stability. –Compatibility with completion equipment and procedures: •Particles should be sized for formation pore throat bridging yet be small enough to pass through completion equipment. •The fluid should be formulated with acid-soluble, water-soluble, oxidizer-degradable or solvent soluble materials, which will not cause precipitates or emulsions. •Breakers should be compatible with formation fluids and horizontal mud system filtrate. •Susceptibility to different types of formation damage varies greatly and is dependent on the formation type and well conditions. •Some formations tolerate a wider range of horizontal mud system composition more than others. •When production is from carbonate fractures, significant amounts of insoluble materials can be tolerated without a significant reduction in productivity. –Usually, fluids which invade these types of formations can be produced back from the well •Lower permeability sandstones and depleted or unconsolidated sandstone reservoirs do not tolerate fluid and particle invasion without causing extensive damage. –Detailed knowledge of the formation, permeability, pore pressure, mineralogy and formation fluid composition must be called upon to assist in selecting the proper horizontal mud system

Multilateral Wells

•Like horizontal wells, multilateral wells justify their existence through their economics. •Defined as a single well with one or more wellbore branches radiating from the main borehole, they can be an exploration well, an infill development well or a re-entry into an existing well. –They all have a common goal of improving production while saving time and money. •Multilateral-well technology has not yet evolved to the point of horizontal-well technology. •The complexity of multilateral wells ranges from simple to extremely complex. •They may be as simple as a vertical wellbore with one sidetrack or as complex as a horizontal extended-reach well with multiple lateral and sublateralbranches. •While existing techniques are being applied and fresh approaches are being developed, complications remain, and the risks and chances of failure are still high.

Horizontal Wells

Why Drill Horizontally:-
•Increasing Production and Reducing Overall Drilling and Completion Costs
•Cost experts agree that horizontal wells have become a preferred method of recovering oil and gas from reservoirs in which these fluids occupy strata that are horizontal, or nearly so,
–they offer greater contact area with the productive layer than vertical wells
–While the cost factor for a horizontal well may be as much as two or three times that of a vertical well, the production factor can be enhanced as much as 15 or 20 times,
•Applications for horizontal wells include the exploitation of thin oil-rim reservoirs, avoidance of drawdown-related problems such as water/gas coning, and extension of wells by means of multiple drainholes.
•During the 1950s, the Soviet Union drilled 43 horizontal wells, a considerable effort with respect to the equipment available then.
•Following their foray into horizontal drilling, the Soviets concluded that while horizontal wells were technically feasible, they were economically disappointing or, in other words, not profitable.
–As a result, they abandoned the method.
•Unlike a directional well that is drilled to position a reservoir entry point, a horizontal well is commonly defined as any well in which the lower part of the wellbore parallels the pay zone.
•The angle of inclination used to drill the well does not have to reach 90°for the well to be considered a horizontal well.

Filtration Control – Additives For Water Based Muds


•Several types of filtration-control additives are used in water-base muds.•Clays –sodium bentonite–Attapulgiteand sepioliteare clays but impart no filtration control
•Polymers–Polymers are the filtration control products used most often in water-base muds–They can range from natural starches and modified cellulose to sophisticated synthetic polymers capable of providing filtration control under high temperatures and hostile conditions Polymers reduce fluid loss in several ways:–Plugging of openings of the filter cake by polymer particles.–Encapsulating solids forming a larger deformable coating or film which reduces the permeability of the filter cake.–Viscosificationof the liquid phase. •Starch, a natural carbohydrate polymer, has been used to control filtration in drilling fluids since the 1930s. –It is widely available as yellow (untreated) and white (modified) starch. –Starches can be used in seawater, salt water, hard water and complex brines. –The most economical and widely used starches are made from corn or potatoes, but starches made from other agricultural products are also available. •Sodium Carboxymethylcellulose(CMC) is a modified natural polymer used for filtration control.–CMC is an effective fluid-loss control additive in most water-base muds.–It works particularly well in calcium treated systems, where it acts to stabilize properties.–CMC is not subject to bacterial degradation and performs well at an alkaline pH. –CMC’s effectiveness decreases at salt concentrations greater than 50,000 mg/l.–subject to thermal degradation at temperatures exceeding 250°F.–Available in Low, medium and high viscosity grades PolyanionicCellulose (PAC) is a modified natural polymer used for: freshwater, seawater, salt and low-solids muds. –It is a high-molecular-weight, polyanioniccellulose similar to CMC, but has a higher degree of substitution. –It is the most widely used fluid-loss control additive and is generally a much better product than CMC.–Good to 275°F –Available as Ultra low viscosity and regular viscosity •Chemical thinners reduce filtration rates by deflocculating the clays, by increasing the fluid phase viscosity and by changing the solids distribution. –Desco and Lignite are effective at deflocculating and lowering fluid loss. •Also available for fluid loss control: –Complex Resin/lignite blends •For HPHT fluid loss control –Polyacrylites •Not in common use anymore •The API fluid loss of these systems is normally zero, or too low to be an effective measure. •The filtration rate of oil muds, unless otherwise noted, refers to the HTHP filtration. •Most oil-and synthetic-base fluids are emulsions. –Their fluid phase is an emulsion with oil or synthetic as the continuous phase and brine as the emulsified phase. –These systems contain from 10 to 50 volume percent brine, usually calcium chloride. –The emulsified brine forms colloid-sized droplets, which are immiscible in the oil or synthetic. –These brine droplets become trapped in the filter cake and reduce filter-cake permeability and fluid loss. Emulsifiers. –Although emulsifiers are not true filtration-control additives, they can reduce filtration by increasing the emulsion strength if the emulsion is unstable. –A sufficiently stable emulsion should be established before treating with filtration-control additives. –If an emulsifier requires lime to be activated, excess lime should be maintained in the mud. •Viscosifiers. –The primary viscosifier in invert emulsion muds is organophilic clay. –Although this clay does not hydrate, it will reduce the filtration rate by providing a colloidal solid for forming a basic filter cake. •The primary filtration-control additives for invert emulsion muds are: –asphalt, –gilsonite(natural asphalt), –amine treated lignite –various other resins –specialized polymers •The asphaltic materials usually provide better filtration control than the amine-treated lignite at equal concentrations and temperature.

Filtration Control -Fundamentals

•Drilling fluids are slurries composed of a liquid phase and solid particles.
–Filtration refers to the liquid phase of the drilling mud being forced into a permeable formation by differential pressure.
–During this process, the solid particles are filtered out, forming a filter cake
•Mud systems should be designed to seal permeable zones as quickly as possible with thin, slick filter cakes.
–In highly permeable formations with large pore throats, whole mud may invade the formation (depending on the size of the mud solids).
–In such situations, bridging agents must be used to block the openings so the mud solids can form a seal. Bridging agents should be at least one-half the size of the largest openings.
–Such bridging agents include calcium carbonate, ground cellulose and a wide variety of other lost-circulation materials
•Filtration occurs under both dynamic and static conditions during drilling operations.
–Dynamic tests are normally run in a laboratory environment using equipment such as a Fann 90
–Static test are run in the field and include the standard API filter press and the HPHT filter press
•For filtration to occur, three conditions are required:
–A liquid or a liquid/solids slurry fluid must be present.
–A permeable medium must be present.
–The fluid must be at a higher pressure than the permeable medium.
•Factors affecting filtration
–Time
–Pressure differential
–Filter cake permeability
–Viscosity
–Solids
•Orientation and composition
•Dynamic Filtration
–Dynamic filtration is significantly different from static filtration, often with considerably higher filtration rates.
–No direct correlation exists between API and HTHP static filtration measurements and dynamic filtration.
–Experience has shown that a mud which exhibits good static filtration characteristics and stability will have satisfactory performance under actual drilling conditions, indicating the dynamic fluid loss is in a satisfactory range.

Filtration Control


•A basic drilling fluid function is to seal permeable formations and control filtration (fluid loss). •Adequate filtration control and the deposition of a thin, low-permeability filter cake are often necessary to prevent drilling and production problems. •Potential problems from excessive filter-cake thickness: –Tight spots in the hole that cause excessive drag. –Increased surges and swabbing due to reduced annular clearance. –Differential sticking of the drillstring due to increased contact area and rapid development of sticking forces caused by higher filtration rate. –Primary cementing difficulties due to inadequate displacement of filter cake. –Increased difficulty running casing.
•Potential problems from excessive filtrate invasion:–Formation damage due to filtrate and solids invasion.–Invalid formation-fluid sampling test.–Formation-evaluation difficulties caused by excessive filtrate invasion, poor transmission of electrical properties through thick cakes–Oil and gas zones may be overlooked because the filtrate is flushing hydrocarbons away from the wellbore, making detection more difficult.