Wang / Economides Advanced Natural Gas Engineering

1. Auflage 2013
ISBN: 978-0-12-799994-4
Verlag: Elsevier Science & Techn.
Format: EPUB
Kopierschutz: 6 - ePub Watermark

E-Book, Englisch, 368 Seiten

Natural gas is playing an increasing role in meeting world energy demands because of its abundance, versatility, and its clean burning nature. As a result, lots of new gas exploration, field development and production activities are under way, especially in places where natural gas until recently was labeled as 'stranded. Because a significant portion of natural gas reserves worldwide are located across bodies of water, gas transportation in the form of LNG or CNG becomes an issue as well. Finally natural gas is viewed in comparison to the recently touted alternatives. Therefore, there is a need to have a book covering all the unique aspects and challenges related to natural gas from the upstream to midstream and downstream. All these new issues have not been addressed in depth in any existing book. To bridge the gap, Xiuli Wang and Michael Economides have written a new book called Advanced Natural Gas Engineering. This book will serve as a reference for all engineers and professionals in the energy business. It can also be a textbook for students in petroleum and chemical engineering curricula and in training departments for a large group of companies.

Autoren/Hrsg.

Wang, Xiuli

Economides, Michael

Leseproben

List of Figures

Figure 1-1 Artist’s rendition of onshore petroleum reservoir 2

Figure 1-2 Artist’s rendition of offshore petroleum reservoir 3

Figure 1-3 Sedimentary environment 4

Figure 1-4 Grain sizes of sediments 5

Figure 1-5 Natural gas reservoirs and trapping mechanisms 7

Figure 1-6 Gas cap 7

Figure 1-7 Phase diagram 10

Figure 1-8 The gas deviation factor for natural gases 15

Figure 1-9 Pseudocritical properties of natural gases 17

Figure 1-10 Pseudocritical temperature adjustment factor, e3 21

Figure 1-11 Viscosity of natural gases at 1 atm 26

Figure 1-12 Viscosity ratio at elevated pressures and temperatures 26

Figure 1-13 Viscosity of gases at 1 atm 27

Figure 2-1 Offshore seismic data acquisition 37

Figure 2-2 -wave impedance from AVO inversion for an offshore natural gas bearing structure 39

Figure 2-3 Calculated Poisson ratios for the zone of interest in Figure 2-2 39

Figure 2-4 Seismic attribute of a structure: Ratios of compressional-reflection to shear-reflection amplitudes 40

Figure 2-5 Drilling rig components 42

Figure 2-6 Measured versus extrapolated from correlations drilling fluid densities at high pressures 46

Figure 2-7 Measured drilling fluid densities of four fluids at depth and at predicted temperatures and pressures 46

Figure 2-8a Onshore wellbore example 50

Figure 2-8b Offshore wellbore example 51

Figure 2-9 Selected completion types 51

Figure 2-10 Gas critical flow rate versus flowing tubing pressure for Example 2-5 55

Figure 3-1 Steady-state flow 63

Figure 3-2 Production versus flowing bottomhole pressure for Example 3-1 67

Figure 3-3 A sketch of an openhole vertical well and its cross section 75

Figure 3-4 Turbulence effects in both horizontal and vertical wells 81

Figure 3-5 Effects of index of permeability anisotropy 82

Figure 3-6 Pushing the limits: maximum with constraints 88

Figure 3-7 Folds of increase between fractured and unfractured wells 94

Figure 3-8 Fluid flow from reservoir to a transverse fracture 95

Figure 3-9 Chart of iterative calculation procedure 97

Figure 3-10 Productivity comparison among vertical and horizontal wells with and without fracture 98

Figure 3-11 Skin versus permeability in the single transversely fractured horizontal well 99

Figure 3-12 Flow geometry in pipe 100

Figure 3-13 Well deliverability for Example 3-9, =1 md, = 3 in 105

Figure 3-14 Well deliverability for Example 3-9, =10 md, = 3 in 105

Figure 3-15 Well deliverability for Example 3-9, k =10 md, = 6.3 in. 106

Figure 3-16 Material balance for Example 3-10 108

Figure 3-17 Production rate, reservoir pressure, and cumulative recovery for Example 3-10 109

Figure 4-1 Generalized gas processing schematic 117

Figure 4-2 Forces on liquid droplet 119

Figure 4-3 Vertical three-phase separator 124

Figure 4-4 Obtain from the downcomer allowable flow 128

Figure 4-5 Two-phase vertical separator 135

Figure 4-6 Three-phase horizontal separator 140

Figure 4-7 Three-phase horizontal separator with a weir 146

Figure 4-8 Water content of sweet natural gas 153

Figure 4-9 Water content correction for sour natural gas 155

Figure 4-10 Hydrate formation prediction 158

Figure 4-11 A sketch of a typical glycol dehydration process 161

Figure 4-12 Gas capacity for packed glycol gas absorbers for ?g = 0.7 at 100°F 161

Figure 4-13 Trays or packing required for glycol dehydrators163

Figure 5-1 Economically preferred options for monetizing stranded natural gas 173

Figure 5-2 Basic pipeline capacity design concept 173

Figure 5-3 Diagram for Example 5-1 176

Figure 5-4 Moody diagram 178

Figure 5-5 Pipeline and compressor station for Example 5-2 179

Figure 5-6 Work needed to compress gas from p1 to p2 181

Figure 5-7 Loading and offloading terminal for LNG and CNG 186

Figure 5-8 Regions actively investigating CNG projects 187

Figure 5-9 Schematic of a CNG vessel 189

Figure 5-10 Schematic of a CNG vessel 190

Figure 5-11 Gas deviation factor as function of pressure and temperature for natural gas 190

Figure 5-12 Value of as function of pressure and temperature for natural gas 191

Figure 5-13 “Hub-and-Spoke” (left) and “Milk-Run” (right) paths for CNG distribution to N receiving sites (terminals T1,…, TN) 193

Figure 5-14 Potential “Hub-and-Spoke” scheme for CNG distribution to island countries in the Caribbean Sea with large consumption of electricity 194

Figure 5-15 Potential “Milk-Run” scheme for CNG distribution to island countries in the Caribbean Sea with small consumption of electricity 195

Figure 5-16 Scheduling of gas delivery from a single source to a single delivery site using two CNG vessels195

Figure 5-17 Scheduling of gas delivery from a single source to a single delivery point using three CNG vessels 195

Figure 5-18 Scheduling of gas delivery from a single source to a single delivery site using n CNG vessels 196

Figure 5-19 Minimum number of vessels, , required to implement a CNG delivery schedule corresponding to various ratios of consumptions rates over loading rates 197

Figure 5-20 Dependence of vessel capacity and total fleet capacity on the number of vessels, n, for Example 5-4 200

Figure 5-21 Dependence of vessel capacity and total fleet capacity on the number of vessels, n, for Example 5-5 203

Figure 5-22 Schedule development for CNG distribution by n similar vessels to N receiving sites serviced successively on a cyclical path as shown in Figure 5-13 204

Figure 5-23 Destinations for CNG delivery using Milk-Run scheme 207

Figure 6-1 Typical LNG plant block flow diagram 211

Figure 6-2 Typical natural gas/refrigerant cooling curves 213

Figure 6-3 Simple cooler/condenser 216

Figure 6-4 Three-stage process for liquefaction 218

Figure 6-5 Simple flash condensation process 220

Figure 6-6 Simplified schematic of Linde process 221

Figure 6-7 APCI process 223

Figure 6-8 p-H diagram for methane 224

Figure 6-9 Simplified APCI process schematic 225

Figure 6-10 Typical propane precooled mixed refrigerant process 228

Figure 6-11 Optimized cascade process 229

Figure 6-12 Single mixed refrigerant loop 230

Figure 6-13 Mixed fluid cascade process (MFCP) 232

Figure 6-14 IFP/Axens Liquefin. process 233

Figure 6-15 Schematic overview of the DMR refrigeration cycles 235

Figure 6-16 LNG carrier size progression 236

Figure 6-17 Moss type LNG tanker 237

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