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Search Petrowiki: Models for wellbore stability
...e calculated. A typical result is shown inFig. 7.2. * Fig. 7.2 โ Pressure profile away from the wellbore. Pseudosteady-State Flow. Pseudosteady-state flow behavior is observed when a well reaches stabili...or constant-rate production under pseudosteady-state conditions, the difference between the flowing wellbore pressure and the average reservoir pressure in the drainage volume is constant, and the pressure dr...e origin of the disturbance. Thus, the magnitude of the disturbance is maximum near its origin (the wellbore) and rapidly terminates away from the ...
The practice of using bottomhole pressure measurements to improve oil and gas production and solve problems of reservoir engineering began around 1930. Initially, pressures were calculated using fluid levels; a later method was to inject gas into the tubing until the pressure became constant. The earliest bottomhole pressure measurements were made with one-time-reading pressure bombs and maximum-indicating or maximum-recording pressure gauges that lacked the accuracy, reliability, or durability of present-day technology. The varied uses of bottomhole pressure and temperature measurements have increased in scope during the past two decades as instrumentation technologies have produced more reliable and accurate tools. These advances have made more applications possible, including use in multilayer reservoirs, horizontal wells, interference testing, and drawdown test interpretation. This chapter is focused mainly on the types of measurements made and the tools available.
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... picture of the drilling or well-services operation, and track well progress to ensure that the new-wellbore placement or completion meets the operator's safety, geologic, and production requirements. Rig co...operations occur. For completion and workover operations, engineers enter reports for: * Downhole wellbore equipment * Wellhead installations * Perforation * Stimulation * Remedial cementing * Producti...t part of the well-operations reporting process. Survey-data management Correct placement of the wellbore to meet geological and production requirements is the primary goal of any drilling operation. In th...
...ction Certain crude oils deposit solid asphaltenes during production. These deposits may plug the wellbore tubing and valves, as well as coat surface safety and process control equipment.[1] Asphaltenes can...temperature, 100oC (data from Ref. 2) [2]. * Fig. 3--A pressure/temperature phase diagram for the stability of asphaltenes in a crude oil.[3] Fig. 3 shows an asphaltene deposition envelope (ADE), a plot of ...e deposition. Combining certain crudes can deposit asphaltenes at the point of mixing (e.g., in the wellbore, flowlines, headers, pipelines, and oil treatment facilities.) Gas lift would favor deposition of a...
These deposits may plug the wellbore tubing and valves, as well as coat surface safety and process control equipment.[1] Asphaltenes can also accumulate in separators and in pipelines. Asphaltenes are a compound class, not a single compound, concentrated in the high-temperature distillation residue of petroleum ( 530 C). The asphaltene class is defined in accord with the solubility sequence illustrated inFigure 1. * Figure 1--Solubility sequence used to define asphaltenes. See Asphaltenes and waxes for a more detailed characterization of asphaltenes.
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...iminating a casing string * Determining whether planned casing running speeds will destabilize the wellbore * Acquiring actual (e.g., not predicted) data inputs for cementing simulating ...models * Reducing the risk of inducing a fracture during cementing operations. Frequent FITs For a hol...istic view of the wellbore conducting FITs more often than is considered the industry norm can be helpful. Offset well informa...
A Formation Integrity Test (FIT) is a test of the strength and integrity of a new formation and it is the first step after drilling a casing shoe track. An accurate evaluation of a casing cement job and of the formation is extremely important during the drilling of a well and for subsequent work.[1] The Information resulting from Formation Integrity Tests (FIT) is used throughout the life of the well and also for nearby wells. Casing depths, well control options, formation fracture pressures, and limiting fluid weights may be based on this information. The main reasons for performing a formation integrity test are to:[2] * Investigate the strength of the cement bond around the casing shoe and to ensure that no communication is established with higher formations.
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... achieved substantial progress toward the correct physical simulation of CHOPS. Adequate simulation models are now available,[1] and progress continues. This section discusses the major physical processes i...ction with sand (CHOPS) wells Permeability-enhanced zone Permeability cannot be defined near the wellbore in liquefied sand. In the approximately 45% porosity zone, it exceeds 10 to 15 darcy for a 100 to 1...y difficult; the values also change with time. * Fig. 3-Permeability as a function of radius: two models. Apparently, no easy way of determining the permeability exists because of the nonhomogeneity of t...
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- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
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... Polymer-gel water-shutoff treatments have proved successful in cases in which faults intersect the wellbore, causing a channel for water flow. If excess water production is bottomwater, the well can be plugg...e complex behavior can result if multiple zones or reservoirs are coproduced either within the same wellbore downhole or mixed on the surface. The mixing can lead to scale deposition, corrosion, and other eff...ects. Artificial lift can also alter the stability of the water. In particular,gas lift and jet pumps are particular artificial lift examples in which...
Extraction of oil and gas from underground reservoirs often is accompanied by water or brine, which is referred to as produced water. As reservoirs mature, especially if secondary or tertiary recovery methods are used, the quantity of water climbs and often exceeds the volume of the hydrocarbons before the reservoir is exhausted. The cost of producing, handling, and disposing of the produced water often defines the economic lifetime of a field and the actual hydrocarbon reserves; therefore, understanding and predicting the aspects, behavior, and problems induced by the produced-water flow is important. This page provides an introduction to produced water, production mechanisms, economics, and characterization. Because the produced water is not usually a revenue stream, the emphasis on water-flow prediction, technology development, and engineering application has not traditionally been a major focus of oil- and gas-production engineering.
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...ate calcium fluoride. Calcium and sodium chloride workover brine also must be flushed away from the wellbore with HCl acid or ammonium chloride brine. Preflushes also displace and isolate incompatible formati...Displaces unreacted HF acid into the formation * Displaces HF-acid reaction products away from the wellbore * Cleans corrosion inhibitors to restore a water-wet condition and good oil/gas effective permeabi...lity * Re-establishes oil/gas saturation near the wellbore Typical overflushes for HF acid treatments are 3% ammonium chloride brine, weak acid (3 to 7.5% HC...
In formations with over 1% carbonate, an HCl or acetic acid preflush dissolves the carbonate to prevent waste of HF acid and formation of the insoluble precipitate calcium fluoride. Calcium and sodium chloride workover brine also must be flushed away from the wellbore with HCl acid or ammonium chloride brine. Preflushes also displace and isolate incompatible formation fluids (either brine or crude oil). Higher concentrations of ammonium chloride ( 3%) are recommended where swellable smectite and mixed layer clays are present.[1][2] For successful HF acidizing, more than 120 gal/ft of HF/HCl acid is usually required.
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...cale and emulsion forming must also be reviewed prior to starting operations. We must ascertain the stability of the zone of interest to determine if the proposed well path is structurally capable of being dri...ic reservoir pressure under static and dynamic conditions to enable reservoir fluid inflow into the wellbore. This difference creates the driving force that drives well productivity. Reservoir Inflow Performa... but also reservoir characteristics like permeability, porosity, length of reservoir exposed to the wellbore, drainage radius, and the pressure driving force. The pressure driving force (reservoir pressure--w...
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...With time, the formation, deposition, and adsorption of hydrates on the internal surfaces of pipes, wellbore, processing facilities, and piping components restricts and disrupts hydrocarbon production, and in...tion, and transmission lines * Stranded-gas transmission to market in a hydrated state * Seafloor stability, affecting subsea-equipment foundations and climate * Energy recovery from hydrates in permafrost ...r a hydrate phase should be considered. As a minimum, hydrates should be included as one extreme in models of fluid phase behavior. In many cases, solid hydrates may control the system phase behavior. Indu...
Hydrates are white, solid, ice-like substances that form at elevated pressures and low temperatures because of an interaction between a liquid water phase and light natural light gas components. The water associated with hydrocarbon production might be in the form of vapor associated with natural gas. Free water might exist in reservoir conditions and travel along with oil and gas. Hydrate formation is unfavorable in most cases since it represents a challenge for flow assurance and production system integrity. With time, the formation, deposition, and adsorption of hydrates on the internal surfaces of pipes, wellbore, processing facilities, and piping components restricts and disrupts hydrocarbon production, and in worst cases, the production ceases.
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... system"--is the single component of the well-construction process that remains in contact with the wellbore throughout the entire drilling operation. Drilling-fluid systems are designed and formulated to per...form efficiently under expected wellbore conditions. Advances in drilling-fluid technology have made it possible to implement a cost-effecti...umps from the surface pits, through the drillstring exiting at the bit, up the annular space in the wellbore, and back to the surface for solids removal and maintenance treatments as needed. The capacity of t...
The drilling-fluid system--commonly known as the "mud system"--is the single component of the well-construction process that remains in contact with the wellbore throughout the entire drilling operation. Drilling-fluid systems are designed and formulated to perform efficiently under expected wellbore conditions. Advances in drilling-fluid technology have made it possible to implement a cost-effective, fit-for-purpose system for each interval in the well-construction process. The active drilling-fluid system comprises a volume of fluid that is pumped with specially designed mud pumps from the surface pits, through the drillstring exiting at the bit, up the annular space in the wellbore, and back to the surface for solids removal and maintenance treatments as needed. The capacity of the surface system usually is determined by the rig size, and rig selection is determined by the well design. For example, the active drilling-fluid volume on a deepwater well might be several thousand barrels. Much of that volume is required to fill the long drilling riser that connects the rig floor to the seafloor. By contrast, a shallow well on land might only require a few hundred barrels of fluid to reach its objective. A properly designed and maintained drilling fluid performs several essential functions during well construction: * Cleans the hole by transporting drilled cuttings to the surface, where they can be mechanically removed from the fluid before it is recirculated downhole.
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