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Search Petrowiki: Fundamentals of gas for gas lift design
...ohydraulic completions have been successfully deployed. Contents * 1 Historical Perspective * 2 Fundamentals of Technology * 2.1 Definitions * 2.2 Objectives of Intelligen-Well Flow Control * 2.3 Equipment... and System Requirements * 2.4 Screening Criteria (Justification and System Design) * 2.5 ...Design Considerations * 2.6 Layered Reservoirs and Horizontal Wells * 2.7 Multilaterals * 2.8 Intervent...
The generic term "intelligent well" is used to signify that some degree of direct monitoring and/or remote control equipment is installed within the well completion. The definition of an intelligent well is a permanent system capable of collecting, transmitting, and analyzing wellbore production and reservoir and completion integrity data, and enabling remote action to better control reservoir, well, and production processes. The concept of the intelligent completion does not generally refer to any capability for automated self-control but relies upon manual interface to initiate instructions to the well. Remote completion monitoring is defined as the ability of a system to provide data, obtained in or near the wellbore, without requiring access and entry for conventional intervention to the well. Remote completion control implies that information and instructions can be transmitted into the well to alter the position or status of one or more completion components. The primary objectives of these abilities are normally to maximize or optimize production/recovery, minimize operating costs, and improve safety. As of 2002, there were some 80 intelligent-well completions with a variety of systems installed worldwide. Hydraulic motive power supplies predominate for these systems, although various hybrid electrohydraulic and optohydraulic completions have been successfully deployed.
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...Production System * 2 Reservoir Inflow Performance * 2.1 Single-Phase Analytical Solutions * 2.2 Gas Well Performance * 2.3 Oilwell Performance * 3 Wellbore Flow Performance * 3.1 Single-Phase Liqu...ods and associated equipment; surface wellhead, flowlines, and processing equipment; and artificial lift equipment. * Fig. 1.1--Production System and associated pressure losses.[1] The reservoir is th...to the surface at economic rates throughout the life of the reservoir. When this occurs, artificial lift equipment is used to enhance production rates by adding energy to the production system. This compo...
Understanding the principles of fluid flow through the production system is important in estimating the performance of individual wells and optimizing well and reservoir productivity. In the most general sense, the production system is the system that transports reservoir fluids from the subsurface reservoir to the surface, processes and treats the fluids, and prepares the fluids for storage and transfer to a purchaser.Figure 1.1 depicts the production system for a single well system. The basic elements of the production system include the reservoir; wellbore; tubular goods and associated equipment; surface wellhead, flowlines, and processing equipment; and artificial lift equipment.
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...f Reservoir Management Benefits * 3.1 Sandstone Reservoir With Combination Drive Supplemented With Gas and Water Injection * 3.2 Sandstone Reservoir With Strong Waterdrive and Crestal ...Gas Injection * 3.3 Sandstone Reservoir With Strong Waterdrive and Selective Well Completion Strategy ... * 3.4 Sandstone Field With Waterflood, Gas Injection, and Miscible Projects * 3.5 Steeply Dipping Sandstone Reservoir With Gravity Stable Mis...
Figure 1.1 illustrates reservoir management processes. The processes are divided into those stewarded by the reservoir management team (RMT) and those guided by the supervisors and managers associated with reservoir management who comprise the reservoir management leadership team (RMLT). The arrows in the RMT box show work flow and how data and opportunities are captured.
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...e of a hook-load sensor. Fig. 15.7--Example of a sonic pit-volume sensor. Fig. 15.8--Example of a gas trap. Fig. 15.9--Example of an FID chromatograph and a total-...gas detector. In addition, exploration and production companies may require specialized services such ...s may be required such as fluid temperature, density, and conductivity. In areas of high H2S or CO2 gas, corresponding sensors that exclusively monitor these gases may be required as well. No other tech...
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...ed in this definition because, although they may impede flow, they either have been put in place by design to serve a specific purpose or do not show up in typical measures of formation damage such as skin...ffins and asphaltenes * Condensate banking. A buildup of condensate around the wellbore can impede gas flow by reducing permeability. SeeFormation damage from condensate banking * Other causes. These c...an include bacterial plugging and gas breakout. See Additional causes of formation damage Quantifying formation damage A commonly used...
Producing formation damage has been defined as the impairment of the unseen by the inevitable, causing an unknown reduction in the unquantifiable. In a different context, formation damage is defined as the impairment to reservoir (reduced production) caused by wellbore fluids used during drilling/completion and workover operations. It is a zone of reduced permeability within the vicinity of the wellbore (skin) as a result of foreign-fluid invasion into the reservoir rock. Typically, any unintended impedance to the flow of fluids into or out of a wellbore is referred to as formation damage. This broad definition includes flow restrictions caused by a reduction in permeability in the near-wellbore region, changes in relative permeability to the hydrocarbon phase, and unintended flow restrictions in the completion itself.
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...yses * 2 Log analyses * 3 Well testing * 4 Pilot projects * 5 Numerical simulation studies * 6 Gas-in-place determination * 7 Reserves determination * 8 Nomenclature * 9 References * 10 Notewort...ategory Core analyses Core analyses are a critical part of analyzing CBM reservoirs to determine gas saturations. Coal cores must be placed in desorption canisters and heated to reservoir temperature...d composition are determined. Desorption continues for up to several months until the rate at which gas is being liberated from the coal becomes very small. At this point, the canisters are opened, and t...
Core analyses are a critical part of analyzing CBM reservoirs to determine gas saturations. Coal cores must be placed in desorption canisters and heated to reservoir temperature. As the coal desorbs, gases are captured, and both their volume and composition are determined. Desorption continues for up to several months until the rate at which gas is being liberated from the coal becomes very small. At this point, the canisters are opened, and the cores can be described. The cores then are crushed in a mill that captures any remaining gas (residual gas), and the milled coal is mixed thoroughly to form a representative sample. An alternative to crushing the entire core is to first slab the core and crush one-half.
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...m of H2O Hydrocarbon Systems Without Hydrates * 2.1 Water Solubility (Dewpoint) in a Hydrocarbon Gas * 2.2 Mutual Solubility of Liquid Water and Liquid Hydrocarbons * 3 Equilibrium of H2O Hydrocar...on Factors Phase Definitions and the Gibbs Phase Rule Phases are homogeneous regions of matter--gas, liquid, or solid--that can be analyzed using common tools such as pressure gauges, thermocouples, ...e degrees of freedom);C number of components; and P number of phases. For example, when excess gas (excess so that its composition does not change) contacts water to form hydrates, there are three p...
The phase behavior of H2O hydrocarbon mixtures differs significantly from the vapor/liquid equilibria of normal hydrocarbons in two ways: the aqueous and hydrocarbon components usually separate, with very low mutual solubility; and hydrates often form with water and hydrocarbons smaller than n-pentane. Water generally is avoided because it is incombustible, and hydrate solids usually are avoided because their presence creates flow assurance difficulties. When hydrocarbon contacts water, the two components separate into two phases in which the mutual component solubility is less than 1.0 mol% at ambient conditions. This splitting of phases affects almost all treatments of H2O hydrocarbon systems and is caused by the different molecular attractions within water and hydrocarbons. Hydrocarbon molecules have a weak, noncharged attraction for each other, while water attracts other water molecules through a strong, charged hydrogen bond. Because hydrogen bonds are significantly stronger than those between hydrocarbon molecules, hydrocarbon solubility in water (and that of water in hydrocarbons) is very small. Hydrogen bonds are responsible for most of the unusual properties water displays. One example is water's very high heat of vaporization, which absorbs large amounts of heat and buffers many hydrocarbon reservoir temperatures. Another example is the very high normal boiling point water has relative to its molecular weight. This chapter discusses H2O hydrocarbon phase equilibria in macroscopic terms, such as temperature, pressure, concentration, and phase diagrams--more easily applied by the engineer--because a quantitative molecular prediction of H2O hydrocarbon phase behavior is beyond the current state of the art. Quantitative predictions of macroscopic phase behavior are illustrated by example, along with a few results from hand calculations, though the many excellent commercial phase equilibria computer programs now available largely have eliminated the need for the hand calculations. This chapter also explains qualitative trends, to help the engineer to understand the implications of temperature, pressure, and composition changes. Such a qualitative understanding and a few hand calculation methods serve as an initial check on the quantitative predictions of computer programs. This chapter is divided into three main sections.
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... difficult to treat and may cause several operational problems in wet-crude handling facilities and gas/oil separating plants. Emulsions can create high-pressure drops in flow lines, lead to an increase ...n and processing: inside reservoirs, wellbores, and wellheads; at wet-crude handling facilities and gas/oil separation plants; and during transportation through pipelines, crude storage, and petroleum pr...eld emulsions at the wellhead and in the wet-crude handling facilities. The primary focus is on the fundamentals and the application of available technologies in resolving emulsions. The chapter looks at the char...
Crude oil is seldom produced alone because it generally is commingled with water. The water creates several problems and usually increases the unit cost of oil production. The produced water must be separated from the oil, treated, and disposed of properly. All these steps increase costs. Furthermore, sellable crude oil must comply with certain product specifications, including the amount of basic sediment and water (BS&W) and salt, which means that the produced water must be separated from the oil to meet crude specifications.
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...hane Industry * 2.1 Characteristics of Successful CBM Projects * 2.2 Comparison With Conventional Gas Reservoirs * 2.3 Appraisal and Development Strategy * 3 CBM Reservoir ...Fundamentals * 3.1 What is Coal? * 3.2 Origin of CBM Reservoirs * 3.3 ...Gas Content * 3.4 ...
Development of the Coalbed Methane Industry Although mines in the U.S. have been venting coal gas intentionally since the 19th century, the production and sale of methane from coalbed wellbores is a relatively recent development. Methane was produced from a few coal seam wells in Wyoming, Kansas, and West Virginia during the early part of the twentieth century; however, the first deliberate attempts to complete wells as coalbed-methane (CBM) producers did not occur until the early 1950s in the San Juan basin of New Mexico. These wells targeted the Fruitland coal seams, which previously were viewed as a high-pressure hazard overlying deeper conventional oil and gas targets. Gas production development from the Fruitland coal seams languished until the mid-1970s when an energy crisis in the U.S. encouraged feasibility studies and investment. In the late 1970s, several companies completed wells in the Fruitland coal seams and found high gas contents and production rates of several hundred Mscf/D.[1]
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...es commonly used in commercial miscible-flooding applications are slug injection, water-alternating-gas (WAG) injection, and gravity-stable injection. The slug process usually involves continuous injecti...tion for CO2-flood MMP (after Mungan[25] and Stalkup[26]). * Fig. 14.8 – Correlation for enriched-gas-drive MMP (after Benham, Dowden, and Kunzman[14]). In field projects in which the displacement was...lance practices after the start of a project include periodic (monthly to quarterly) studies of the gas/oil-ratio (GOR) and water/oil-ratio (WOR) trends in producing wells and the indicated adjustments n...
To put miscible flooding into perspective, it is instructive to compare the performance of a miscible flood to that of a waterflood. Although it is impossible to define a "typical" flood, the simplistic example shown inFigure 1.1 introduces the physics of the process and illustrates the level of incremental recovery and sweep often achieved with miscible flooding. This example is based on simulation results for the Means Lower San Andres reservoir in west Texas.[1]
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