Oil and gas production handbook An introduction to oil ... - ABB Group

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Optimal production targets and maximum utilization of production resources are achieved through the use of several sources of information, such as reservoir mass balance calculations and depletion strategies, well test results and use of simulation models. This is made possible by linking skills, data and tools together in real time – independent of location. Some of the enabler technology areas are: 1. A system and communication IT infrastructure 2. Applications for remote operations and remote operations support 3. Reservoir management and drilling operations 4. Production optimization 5. Information management systems 6. Operation support and maintenance 8.2.1 Reservoir management and drilling operations Solution for data acquisition, modeling and visualization between facility operators and central company experts to provide: • Drilling simulation and visualization, automatic diagnostics and decision support, real-time measurements while drilling in order to locate the best targets • Reservoir models based on real-time reservoir data, analysis of 4D seismic, in-situ measurements of changes. On-line integration with well-serviced company data • Optimization models for increased production, based on in-reservoir properties during production, with decision support incorporated to improve productivity 8.2.2 Production optimization Optimizing the production or improving productivity is a complex problem. In addition to the production optimization of the downhole, subsea and topside process, one has to consider operational costs, hardware damage, reservoir performance, environmental requirements and operational difficulties within each well and/or topside. To further complicate optimization, the individual challenges will change over time, e.g., reservoir behavior changes as an effect of depletion, shutdown of wells due to slugging, failed sensors and the change of efficiencies within the topside process system. Some of the applications included in production optimization are: 112
• Flowline control to stabilize multiphase flow in gathering systems, risers and flow lines. • Well control that will stabilize and optimize gas lift and naturally flowing wells. This application should prevent flow and pressure surges while maintaining minimal backpressure and maintain maximum production as well as continuing production at the optimum lift gas rate. • Gas-lift optimization is provided to ensure the best possible distribution of lift-gas between gas lifted wells. • Slug management helps mitigate variations in inflow impact. The separation and hydrocarbon processing during startup, upset and normal operation. • Well monitoring systems (WMS) are used to estimate the flow rates of oil, gas and water from all the individual wells in an oil field. The real-time evaluation is based on data from available sensors in the wells and flow lines. • Hydrate prediction tools help to avoid hydrate formation, which may occur if a subsea gathering system is allowed to cool down too much before the necessary hydrate preventive actions are performed. • Optimal operation is defined by a set of constraints in the wells and production facilities. A constraint monitoring tool monitors the closeness to all constraints. This provides decision support for corrective actions needed to move current operation closer to its true potential. • Advanced control and optimization solutions to improve the performance of product quality control, while adhering to operating constraints. This is typically done with two technologies: model predictive control to drive the process closer to operating targets, and inferential measurement to increase the frequency of product quality feedback information. • Tuning tools are designed to optimize and properly maintain the optimal setting of control loops in the process automation system. 8.2.3 Asset optimization and maintenance support An asset optimization (AO) system reduces costly production disruptions by enabling predictive maintenance. It records the maintenance history of an asset and identifies potential problems to avert unscheduled shutdowns, maximize up-time and operate closer to plant production prognoses. This functionality supports maintenance workflow as the AO system communicates with a maintenance system, often denoted as a computerized maintenance management system (CMMS). 113
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Håvard Devold Oil and gas producti
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PREFACE This handbook has been comp
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4.1.1 Pipelines and risers ........
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9.1.7 Biofuels ....................
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arrels per day in October, 1861, an
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2 Facilities and processes The oil
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Although there is a wide range of s
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day GOSP. Product is sent from the
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FPSO: Floating Production, Storage
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water depths from 300 up to 3,000 m
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For gas gathering systems, it is co
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2.3.5 Utility systems Utility syste
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for the operation of the pipeline.
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Photo: DOW, Terneusen, Netherlands
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particular crude is merely a measur
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3.1.3 Condensates While the ethane,
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each different parts of the structu
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around 4.5 MPa. During production,
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well from caving in and to help in
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well to add multiple completions to
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Variable flow choke valve. The vari
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motor drives a reciprocating beam,
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The cycle starts with the plunger f
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4 The upstream oil and gas process
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The desired setting for each well a
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Emergency valves (EVs) are sectioni
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The environmental regulations in mo
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Heat exchangers of various forms ar
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• Reciprocating compressors, whic
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Figure 8. Compressor state diagram
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4.4 Oil and gas storage, metering a
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Gas metering is less accurate than
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5 Midstream facilities Raw natural
Page 69 and 70: o o Acid gas has a high content of
Page 71 and 72: 5.3.1 Acid gas removal Acid gases s
Page 73 and 74: 5.3.4 Nitrogen rejection Excessive
Page 75 and 76: 5.4 Pipelines Pipeline installation
Page 77 and 78: pressure-reducing turbines (or brak
Page 79 and 80: LNG carriers are used when the tran
Page 81 and 82: Typical LNG train power use is abou
Page 83 and 84: The dual cycle mixed refrigerant (D
Page 85 and 86: 6 Refining Up to the early 1970s, c
Page 87 and 88: 3 and 4 and boiling points -42 °C
Page 89 and 90: Figure 20. Refinery process flow di
Page 91 and 92: Distillate hydrotreater units desul
Page 93 and 94: 2 H 2 S + O 2 → S 2 + 2 H 2 O The
Page 95 and 96: 7 Petrochemical Petrochemicals are
Page 97 and 98: products. Almost all aromatics come
Page 99 and 100: formed into molded products. Nylon
Page 101 and 102: chains with only two, three or four
Page 103 and 104: appliance housings, dishwasher-proo
Page 105 and 106: ubber is a vinyl polymer, and is ve
Page 107 and 108: terephthalic acid (PTA) as the pref
Page 109 and 110: • Field instrumentation: sensors
Page 111 and 112: • Optimization of various process
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Page 119: system by means of the available co
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Page 125 and 126: training facilities are often conne
Page 127 and 128: Therefore use of large variable spe
Page 129 and 130: desalination of seawater though dis
Page 131 and 132: Polyelectrolyte Methanol (MEG) TEG
Page 133 and 134: · Mandatory radio system · Securi
Page 135 and 136: 9 Unconventional and conventional r
Page 137 and 138: eleases bitumen from the oil sand,
Page 139 and 140: after well completion and fracturin
Page 141 and 142: gas - combined. However, research i
Page 143 and 144: 9.1.8 Hydrogen Although not a hydro
Page 145 and 146: and gas, the remainder is coal, pea
Page 147 and 148: The main contribution to sea level
Page 149 and 150: 10 Units Some common units used in
Page 151 and 152: 11 Glossary of terms and acronyms A
Page 153 and 154: MEG MEK MMA MP MPA MPG / USP MSDS M
Page 155 and 156: 12 References Web online sources an
Page 157 and 158: cumene ............................
Page 159 and 160: polybutadiene .....................
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