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Search Petrowiki: Core analyses in tight gas reservoirs
...Corrections to core measurements of permeability Before selecting a method of determining permeability in a specific ...reservoir, one must first be assured that the core measurements are appropriate for reservoir conditions. Sample collection, selection, and preparatio... OnePetro * 8 External links * 9 See also Klinkenberg effect The permeability of a sample to a gas varies with the molecular weight of the ...
Before selecting a method of determining permeability in a specific reservoir, one must first be assured that the core measurements are appropriate for reservoir conditions. Sample collection, selection, and preparation are important steps in ensuring that the data set represents the geology at in-situ conditions; some precautions are discussed inRelative permeability and capillary pressure. Adjustments may be necessary for the type of test fluid and for pressure effects. The permeability of a sample to a gas varies with the molecular weight of the gas and the applied pressure, as a consequence of gas slippage at the pore wall. The correction parameter b is determined by conducting the test at several flowing pressures and extrapolating to infinite pressure.
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...PEH:Tight Gas Reservoirs Publication Information Petroleum Engineering Handbook Larry W. Lake, Editor-in-Chief Volu...chnologies H.R. Warner Jr., Editor Copyright 2007, Society of Petroleum Engineers Chapter 7 โ Tight Gas Reservoirs By Stephen A. Holditch, SPE, Texas A&M U. Pgs. 305-361 ISBN 978-1-55563-122-2 Get permission ...for reuse Introduction Tight gas is the term commonly used to refer to low permeability ...
Tight gas is the term commonly used to refer to low permeability reservoirs that produce mainly dry natural gas. Many of the low permeability reservoirs that have been developed in the past are sandstone, but significant quantities of gas are also produced from low permeability carbonates, shales, and coal seams. Production of gas from coal seams is covered in a separate chapter in this handbook. In this chapter, production of gas from tight sandstones is the predominant theme. However, much of the same technology applies to tight carbonate and to gas shale reservoirs.
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...nate PCP system configurations * Artificial lift selection methods * Associated and nonassociated gas * Authority for expenditures (AFE) B * Barite sag * Bessel functions in transient analysis * ...ware * Cementing operations * Challenges in drilling salt formations and rubble zones * Chemical gas tracers * Chemical water tracers * CHOPS operational and monitoring issues * CHOPS reservoir ass...oduction * Controlling precipitates due to acidizing * Converting geothermal to electric power * Core analyses in ...
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...PEH:Gas Reservoirs Publication Information Petroleum Engineering Handbook Larry W. Lake, Editor-in-Chief Volu...hysics Edward D. Holstein, Editor Copyright 2007, Society of Petroleum Engineers Chapter 10 โ Gas Reservoirs Mark A. Miller, Consultant Edward D. Holstein, Consultant Pgs. 981-1036 ISBN 978-1-55563-120-8...permission for reuse This chapter addresses the flow characteristics and depletion strategies for gas reservoirs. The focus will be primarily on nonassociated accumulations, but much of the fluid behavior, flow r...
Natural petroleum gases contain varying amounts of different (primarily alkane) hydrocarbon compounds and one or more inorganic compounds, such as hydrogen sulfide, carbon dioxide, nitrogen (N2), and water. Characterizing, measuring, and correlating the physical properties of natural gases must take into account this variety of constituents. Phase Behavior of Natural-Gas Reservoirs A widely accepted system for categorizing petroleum reservoir fluids is based on five classes: low-shrinkage (crude) oils, high-shrinkage (volatile) oils, retrograde-condensate gases, wet gases, and dry gases. Typical phase diagrams for the gas categories are shown inFigs.
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...PEH:Estimation of Primary Reserves of Crude Oil, Natural Gas, and Condensate Publication Information Petroleum Engineering Handbook Larry W. Lake, Editor... Society of Petroleum Engineers Chapter 18 โ Estimation of Primary Reserves of Crude Oil, Natural Gas, and Condensate Ron Harrell, SPE, Ryder Scott Co., Chap Cronquist, SPE Consultant Pgs. 1479-157... has come ongoing technological development that provides better tools and techniques for analyzing reservoirs and reservoir fluids as well as greater understanding of how reservoir geology affects reservoir pe...
Reserves are those quantities of petroleum which are anticipated to be commercially recovered from known accumulations from a given date forward. All reserves estimates involve some degree of uncertainty. The uncertainty depends chiefly on the amount of reliable geologic and engineering data available at the time of the estimate and the interpretation of these data. The relative degree of uncertainty may be conveyed by placing reserves into one of two principal classifications, either proved or unproved. Unproved reserves are less certain to be recovered than proved reserves and may be further subclassified as probable and possible reserves to denote progressively increasing uncertainty regarding their recoverability.
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...ermission for reuse Introduction The first hydraulic fracturing treatment was pumped in 1947 on a gas well operated by Pan American Petroleum Corp. in the Hugoton field.[1] Kelpper Well No. 1, located ...947, hydraulic fracturing has become a common treatment for stimulating the productivity of oil and gas wells. Hydraulic fracturing is the process of pumping a fluid into a wellbore at an injection rate... pumping operation ceases, the pressure in the fracture decreases, and the fracture closes. In deep reservoirs, man-made ceramic beads are used to hold open or "prop" the fracture. In shallow ...
The first hydraulic fracturing treatment was pumped in 1947 on a gas well operated by Pan American Petroleum Corp. in the Hugoton field.[1] Kelpper Well No. 1, located in Grant County, Kansas, was a low-productivity well, even though it had been acidized. The well was chosen for the first hydraulic fracture stimulation treatment so that hydraulic fracturing could be compared directly with acidizing. Since that first treatment in 1947, hydraulic fracturing has become a common treatment for stimulating the productivity of oil and gas wells. Hydraulic fracturing is the process of pumping a fluid into a wellbore at an injection rate that is too great for the formation to accept in a radial flow pattern.
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...hen direct measurement is limited. Based on evaluator's assessment of similarities of the analogous reservoir(s) together with the development plan. Glossary of Petroleum Resources Management System - June 2018 ...(revised version) Reservoirs that have similar rock properties (e.g., petrophysical, lithological, depositional, diagenetic, and...luation. Glossary of Petroleum Resources Management System - June 2018 (revised version) A natural gas found in contact with or dissolved in crude oil in the reservoir. It can be further categorized as ...
Equal to P1. Glossary of Petroleum Resources Management System - June 2018 (revised version) The process (and associated costs) of returning part or all of a project to a safe and environmentally compliant condition when operations cease. Examples include, but are not limited to, the removal of surface facilities, wellbore plugging procedures, and environmental remediation. In some instances, there may be salvage value associated with the equipment removed from the project. ADR costs are presumed to be without consideration of any salvage value, unless presented as "ADR net of salvage." Arithmetic summation of incremental categories may yield different results from probabilistic aggregation of distributions. Method used in resources estimation in the exploration and early development stages (including improved recovery projects) when direct measurement is limited. Based on evaluator's assessment of similarities of the analogous reservoir(s) together with the development plan.
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...se Type * 7.2 Two-Phase Flash * 7.3 Density * 7.4 Component Partitioning * 7.5 Viscosity * 7.6 Gas/Oil Interfacial Tension (IFT) * 7.7 Black-Oil PVT Models * 7.8 Equation-of-State Models * 7.9 Th...igent Wells * 9.7 Integrated Reservoir and Surface Facilities Models * 9.8 Simulation of Multiple Reservoirs * 9.9 Use of Larger Models * 9.10 History Matching and Production Forecasting * 10 Nomenclature ...irstn (primary) equations simply express conservation of mass for each of n components such as oil, gas, methane, CO2, and water, denoted by subscript I 1,2,โฆ,n. In the thermal case, one of the "compon...
Any reservoir simulator consists of n m equations for each of N active gridblocks comprising the reservoir. These equations represent conservation of mass of each ofn components in each gridblock over a timestep ฮt from tn to tn 1 . The firstn (primary) equations simply express conservation of mass for each of n components such as oil, gas, methane, CO2, and water, denoted by subscript I 1,2,โฆ,n. In the thermal case, one of the "components" is energy and its equation expresses conservation of energy. An additional m (secondary or constraint) equations express constraints such as equal fugacities of each component in all phases where it is present, and the volume balanceSw So Sg Ssolid 1.0, whereS solid represents any immobile phase such as precipitated solid salt or coke. There must be n m variables (unknowns) corresponding to these n m equations. For example, consider the isothermal, three-phase, compositional case with all components present in all three phases.
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...d laboratory observations associated with asphaltene precipitation during primary depletion and IOR gas injection follows. Aphaltene Precipitation During Primary Depletion. In normal pressure depletion,... reservoirs that experience asphaltene precipitation usually have the following characteristics[2]: * The flui... encountered serious precipitation problems during production. Asphaltene Precipitation During IOR Gas Injection. The injection of hydrocarbon gases or CO2 for IOR promotes asphaltene precipitation. Num...
Deposition of the high-molecular-weight components of petroleum fluids as solid precipitates in surface facilities, pipelines, downhole tubulars, and within the reservoir are well-recognized production problems. Depending on the reservoir fluid and the type of recovery process, the deposited solid may consist of asphaltenes, waxes, or a mixture of these materials. The deposits also can contain resins, crude oil, fines, scales, and water.[1]
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...opment history For a long time, the Fruitland formation coals were recognized only as a source of gas for adjacent sandstones. In the 1970s, after years of encountering ...gas kicks in these coals, operators recognized that the coal seams themselves were capable of commercia...l gas rates. CBM development benefited greatly from drilling and log data compiled from previous wells ta...
Case studies can be instructive in the evaluation of other coalbed methane (CBM) development opportunities. The San Juan basin, located in New Mexico and Colorado in the southwestern U.S. (Figure 1), is the most prolific CBM basin in the world. It produces more than 2.5 Bscf/D from coals of the Cretaceous Fruitland formation, which is estimated to contain 43 to 49 Tscf of CBM in place.[1] For a long time, the Fruitland formation coals were recognized only as a source of gas for adjacent sandstones. In the 1970s, after years of encountering gas kicks in these coals, operators recognized that the coal seams themselves were capable of commercial gas rates. CBM development benefited greatly from drilling and log data compiled from previous wells targeting the deeper sandstones and an extensive pipeline infrastructure that was built to transport conventional gas. These components, along with a U.S. federal tax credit and the development of new technologies such as openhole-cavity completions, fueled a drilling boom that resulted in more than 3,000 producing CBM wells by the end of 1992. The thickest Fruitland coals occur in a northwest/southeast trending belt located in the northeastern third of the basin. Total coal thickness in this belt locally exceeds 100 ft and individual coal seams can be more than 30 ft thick.[1] The coals originated in peat swamps located landward (southwest) of northwest/southeast trending shoreline sandstones of the underlying Pictured Cliffs formation. The location of the thickest coals (Figure 1) coincides with the occurrence of overpressuring, high gas content, high coal rank, and high permeabilities in the San Juan fairway ("fairway"). The overpressuring is artesian in origin and is caused by water recharge of the coals through outcrops along the northern margin of the basin. This generates high vertical pressure gradients, ranging from 0.44 to 0.63 psi/ft,[2] which allow a large amount of gas to be sorbed to the coal. Coal gas in the San Juan basin can contain up to 9.4% CO2 and 13.5% C2 .[3] Chemical analyses suggest that thermogenic gases have been augmented by migrated thermogenic and secondary biogenic gas sources, resulting in gas contents ranging up to 700 ft 3 /ton.[4] Coal rank in the fairway ranges from medium- to low-volatile bituminous and roughly coincides with those portions of the basin that were most deeply buried. Coals in the fairway typically have low ash and high vitrinite contents, resulting in large gas storage capacities and excellent permeabilities of 10 md from well-developed cleat systems. Southwest of the fairway, Fruitland coals are typically 20 to 40 ft thick and are considerably underpressured with vertical pressure gradients in some areas of less than 0.20 psi/ft.[5]
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