PA KED ED REA TOR OPERATING MANUAL - LSU Unit Operations Lab
QUE$TOR manual
description
Transcript of QUE$TOR manual
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Table of Contents
Table of Contents 1
About the Quick Start Guide 65
Getting Started 67
From the taskbar Start button 67
From your PC desktop 67
Creating a New Project 68
Selecting the Project Properties 69
Entering Your Field Level Data 72
Creating a Production Profile 74
Setting the Design Flowrates 76
Setting the Number of Wells 77
Setting the Wellhead Conditions 78
Selecting a Concept - Offshore 79
Selecting a Concept - Onshore 80
Using the Field Development Schematic 82
Adjusting a Component 83
Inputs 83
Sub-components 84
Cost sheet 85
Calculating the Operating Costs 86
Scheduling the Capital Costs 87
Generating the Investment and Production Profile 88
Saving Your Project 89
Opening a Saved Project 89
About QUE$TOR 90
Capabilities 90
Cost Databases 90
Estimate Basis 92
Recommended System Specifications 93
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Minimum system specifications: 93
Before installing QUE$TOR 93
Installation requirements 93
Exporting to Microsoft Excel from QUE$TOR 94
Contacting Customer Support 95
Copyright 97
QUE$TOR Structure 98
Once on the FDS 99
About Project Properties 100
Units of Measure 101
Main Product 101
Location 101
Creating Procurement Strategies 103
About Field Level Data 105
Field Characteristics 106
Fluid / Profile Characteristics 108
Liquid data 108
Gas data @ STP 108
Well data 109
Miscellaneous 110
Miscellaneous Items 110
Temperature 110
BOEEquivalents 111
About Production Profiles 112
Production Profile Edit 113
Production Profile 114
Design Flowrates 116
Peak daily average production rates 116
Design rates 116
Water injection 117
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Gas injection 117
Number of Wells 118
About the Concept Selector 119
Concept Selection for New Projects 120
Concept Selection for Existing Projects 121
Field Development Schematic 123
Topsides docking to substructures 124
Pipelines, Power cables & linking components 124
About Component Level Data 127
Cost Summary Tree 127
Component Toolbar 128
Component Duplication 130
Well and Flow Distribution 133
Offshore Cost Centres 136
Equipment Costs 136
Materials Costs 137
Fabrication Costs 137
Installation Costs 138
Hook-up and Commissioning (HUC) Costs 138
Design and Project Management Costs 138
Insurance and Certification costs 139
Contingency 139
About Offshore Components 140
Cost Summary Tree 140
Input Panel 141
Cost Estimate Sheets 141
About Topsides 142
User Interface 143
Inputs 143
Facilities 144
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Cost Estimate 145
Primary Inputs 146
Functions 146
Capacities 147
Configuration 149
Substructure 149
Include electrical buildings 150
Deck 150
Installation and HUC 151
Product Export 152
Gas Disposal / Export 153
Design Conditions 154
Reservoir Pressure 154
Dry tree wellhead temperature 154
Arrival temperature 154
Acid Gas / High T / High P 155
Maximum monthly average air temperature 155
Facilities 156
Manifolding 158
Multiphase metering 158
Operating pressures 159
Design pressures 159
Oil Processing 161
Oil Export 166
Pipeline Sizing 166
Details 167
Driver 167
Derating Factor 167
Capacity 168
Driver Model 168
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Pump Weight 168
Pump Driver Weight 168
Metering Capacity 168
Metering Weight 168
Gas Processing 169
Cooling 170
Acid Gas Removal 170
Membrane Unit 170
Conventional Acid Gas Removal 172
Dehydration 173
Dewpoint Control 175
Stabiliser 176
Metering 176
Gas Compression 177
Compressor Classification and Selection 177
Flash gas 177
Export gas 178
Gas lift 178
Gas injection 178
Compressor Sizing 178
Compressor type 178
Number of stages 179
Power 179
Derated power 179
Number of compressors 179
Design duty/compressor 179
Driver type 179
Driver model 180
Driver rating 180
Pipeline Sizing 180
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Coolers 181
Weights 181
Water Injection 182
Details 183
Driver 183
Configuration 184
Weight 184
Custom Equipment 185
General 187
Bulk materials, utilities and operating weight 187
Utilities 187
Power 187
Civils 187
Cost sheet 187
Example 188
Cost sheet 189
Custom equipment library 190
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Control and Communications 191
Monitoring and Control 191
Telemetry System 192
On-Platform Communications 192
Off-Platform Communications 192
Drilling Facilities 193
Rig details 193
Number of rigs 194
Maximum measured depth 194
Power 194
Weights 194
Quarters 196
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Existing facilities 196
Number of beds 197
Cabin size 197
Helideck 197
Platforms with No Quarters 197
Manning 198
Process Utilities 199
Process Support Utilities 200
General Utilities 200
Ancillaries 201
Chemical Injection 202
Flare 207
Gas Design Capacity 207
Flare Type 207
Flare Tower Type 208
Power 209
Power Requirement 209
Emergency Power 210
Generation and distribution 211
Distribution only 211
Derating 211
Capacity 211
Driver 211
Weights 212
Electrical Buildings 213
Equipment List 214
Equipment Costs 216
Freight 216
Bulk Materials Costs 217
Steel 217
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Piping 217
Electrical bulks 218
Instrument bulks 218
Others 218
Freight 219
Fabrication Costs 220
Loadout and Seafasten 220
Installation Costs 221
Tugs Transport Spread 221
Barge Transport Spread 221
Installation Spread 221
Hook-up and Commissioning Costs 223
Atshore HUC 223
Inshore HUC 223
Offshore HUC 223
HUC Accommodation (flotel) 224
General Costs 225
Design 225
Project Management 225
Certification 226
Insurance 226
Contingency 226
Hints on Developing Topsides Projects 227
Sour Gas Service 227
Gas lift projects 228
About Jackets 229
Calibration of jacket weights 229
Inputs 231
Jacket Type 231
Water Depth 231
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Topsides Operating Weight 232
Installation Method 232
Jacket attachments 233
Soil conditions 233
Environmental conditions 233
Regional jacket steel factor 234
Materials Costs 235
Jacket Steel 235
Piles 235
Conductors 235
Anodes 235
Installation aids 235
Freight 236
Fabrication Costs 237
Loadout and Seafasten 237
Installation Costs 238
Tugs Transport Spread 238
Barge Transport Spread 238
Installation Spread 238
General Costs 239
Design 239
Project Management 239
Certification 240
Insurance 240
Contingency 240
Lightweight Structures 241
Guyed Caisson 241
Braced Monotower 242
Lightweight Jacket 242
About Gravity Based Structures 243
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Inputs 244
GBS Type 244
Water Depth 244
Topsides Operating Weight 244
Storage Capacity 244
Inshore Deck Mating 244
Conductors 245
Materials Costs 246
Concrete 246
Steel 246
Solid Ballast 246
Mechanical Outfitting 247
Conductors 247
Freight 247
Fabrication Costs 248
GBS 248
Mechanical Outfitting 248
Installation Costs 249
Deck Mating 249
Deck / Shaft HUC 249
Tow Out 249
Installation 249
General Costs 250
Design 250
Project Management 250
Certification 251
Insurance 251
Contingency 251
About Offshore Pipelines 252
Pipeline Links 253
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Length 253
Water depth 254
Flow type 254
To / From 254
Pipeline Sizing 256
General 256
Material 257
Liquid / Oil / Methanol Flowrate 258
Water Flowrate 258
Gas Flowrate 258
Pressure In 258
Pressure Out 258
Fluid Temperature 258
Buckle Arrestors 258
Nominal Diameter 259
Corrosion Allowance 259
Wall Thickness 259
Pipeline Installation 260
Lay Vessel 260
Pipeline Crossings 261
Buried Length 261
Coating 261
Weight Coat 261
Cathodic Protection 262
Insulation Material 262
Insulation U-value 262
Export End 263
Termination details 263
Pipeline end terminations (PLETs) 264
Receiving End 265
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Termination details 265
Pipeline end terminations (PLETs) 266
About Pipeline Terminations 267
Riser - Steel Fixed 268
Riser Linepipe 268
Coating 268
Insulation 268
Anodes 268
Clamps 269
Spools, Flanges & Fittings 269
Subsea Emergency Shutdown Valve Systems 269
Riser - Steel Retrofit 270
Riser Linepipe 270
Coating 270
Insulation 270
Anodes 270
Clamps 270
Spools, Flanges & Fittings 271
Subsea Emergency Shutdown Valve Systems 271
Riser - Steel Catenary 272
Riser Linepipe 272
Coating 272
Insulation 272
Anodes 272
Strakes 273
Buoyancy 273
Flex Joint 273
Spools, Flanges & Fittings 273
Subsea Emergency Shutdown Valve Systems 273
Riser - Flexible Lazy S 274
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Riser Linepipe 274
Riser Arch Buoy System 274
Spools, Flanges & Fittings 274
Subsea Emergency Shutdown Valve Systems 274
Riser - J-Tube 275
Riser Linepipe 275
Coating 275
Insulation 275
Anodes 275
Clamps 276
Spools, Flanges & Fittings 276
Subsea Emergency Shutdown Valve Systems 276
Riser - Top Tension 277
Riser Linepipe 277
Coating 277
Insulation 277
Anodes 277
Tensioning Equipment 278
Buoyancy Cans 278
Lower Assembly 278
Foundation 278
Spools, Flanges & Fittings 278
Subsea Emergency Shutdown Valve Systems 278
Riser - Single Leg Hybrid 279
Flexible Linepipe 279
Rigid Linepipe 279
Coating 279
Insulation 280
Anodes 280
Upper Assembly 280
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Buoyancy Cans 280
Lower Assembly 280
Foundation 280
Spools, Flanges & Fittings 280
Subsea Emergency Shutdown Valve Systems 280
Pipeline Tie-In 282
Pipeline Tie-In 282
Spools, Flanges & Fittings 282
Subsea Emergency Shutdown Valve Systems 282
Shore Approach 284
Shore Approach Materials 284
Subsea Emergency Shutdown Valve Systems 284
Pipeline End Terminations (PLETs) 285
Structure 285
Valve 285
Protection Structure 285
Mudmat 285
Jumper 286
Jumper Connectors 286
Installation Durations 287
Pipelay Spreads 287
Diving Support Vessel 287
Trench Vessel 288
Survey Vessel 288
Dredge Vessel 288
Rock Install Vessel 288
Materials Costs 289
Linepipe 289
Coating 289
Weight Coating 289
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Insulation 290
Onshore Welding and Reeling 290
Terminations 290
PLETs 290
Freight 290
Installation Costs 291
Pipelay Spreads 291
Diving Support Vessel 291
Testing & Commissioning Equipment 291
Trench Vessel 291
Survey Vessel 292
Dredge Vessel 292
Rock Install Vessel 292
Shore Approach 292
General Costs 293
Design 293
Project Management 293
Certification 294
Insurance 294
Contingency 294
About Offshore Power Cables 295
Power Cable Links 296
Water depth 296
To / From 297
Cable Sizing 298
General 298
Power 298
Voltage 298
Conductor Size 298
Burial 298
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Rock Installation 299
Termination details 300
Export End 300
Receiving End 300
Installation Durations 301
Cable laying 301
Survey Vessel 301
Rock Install Vessel 301
Materials Costs 302
Cable 302
Gravel 302
Export End Riser 302
Export End Connection System 302
Receiving End Riser 302
Receiving End Connection System 303
Landfall System 303
Freight 303
Installation Costs 304
Cable Lay Spread 304
Rock Install Vessel 304
Survey Vessel 304
Testing & Commissioning Equipment 304
Shore Approach 304
General Costs 305
Design 305
Project Management 305
Certification 306
Insurance 306
Contingency 306
About Semi-submersibles 307
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Primary Inputs 308
Semi-submersible Type 308
Semi-submersible Generation 309
Topsides Operating Weight 309
Water Depth 309
Number of Risers 309
Conversion Upgrades 309
Length of Sea Trials 310
Additional Load 310
Buoyancy Aid 310
Drilling Facilities 310
Marine transport 311
Mooring System 312
Mooring Type 312
Anchor Type 313
Soil Condition 313
Environmental Conditions 314
Mooring Chain Size 314
Number of Mooring Lines 315
Chain Length 315
Rope Length 315
Wire Length 315
Equipment Costs 316
Vessel Purchase 316
Anchors 316
Materials Costs 317
General Upgrade 317
Marine Upgrade 317
Drilling Upgrade 317
Mooring Upgrade 317
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Mooring Chain 317
Mooring Wire 318
Mooring Rope 318
Mooring Terminations 318
Buoyancy Aid 318
Freight 319
Fabrication Costs 320
Strip Out 320
General Upgrade 320
Marine Upgrade 320
Drilling Upgrade 320
Mooring Upgrade 320
Buoyancy Aid 320
Installation Costs 321
Transport from fabrication yard 321
Mob / Demob and Tow out 321
Installation 321
Hook-up and Commissioning Costs 322
Sea Trials and Marine Commissioning 322
General Costs 323
Design 323
Project Management 323
Certification 324
Insurance 324
Contingency 324
About Spar Buoys 325
Primary Inputs 326
Spar Type 326
Riser Wall Type 327
Number of Platform Wells 327
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Water Depth 327
Distance to Installation Site 327
Topsides Operating Weight 327
Marine transport 327
Mooring System 329
Mooring Type 329
Anchor Type 330
Soil Condition 330
Environmental Conditions 331
Mooring Chain Size 331
Number of Lines 332
Chain Length 332
Rope Length 332
Wire Length 332
Materials Costs 333
Hull Structure 333
Hull Outfitting and Marine Systems 334
Mooring Chains 334
Mooring Wire / Rope 334
Mooring Terminations 334
Anchors 334
Riser Pipe (conductors) 334
Riser Connectors and Buoyancy Cans 334
Riser Components 335
Fabrication Costs 336
Hull Structure 336
Hull Outfitting and Marine Systems 336
Riser Pipe (conductors) 336
Hull Joining 336
Installation Costs 337
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Transport from Fabrication Yard 337
Transport to Installation Site 337
Hull Installation Duration 337
Anchor and Mooring Installation 337
General Costs 339
Design 339
Project Management 339
Certification 340
Insurance 340
Contingency 340
About Tankers 341
Primary Inputs 342
Tanker Type 342
Tanker Size 343
Water Depth 343
Production Rate 343
Water Injection Rate 343
Gas Export/Injection 343
Days of Storage 343
Number of Risers 343
General Upgrade 343
MarineUpgrade 344
Tanker Strengthening 344
Length of Sea Trials 344
Mooring Option 344
Added Production Facilities Weight 345
Elevated Deck 345
Gas Lift 345
Marine transport 345
Mooring System 346
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Mooring Type 346
Anchor Type 347
Soil Condition 347
Environmental Conditions 348
Mooring Chain Size 348
Number of Lines 349
Chain Length 349
Rope Length 349
Wire Length 349
Equipment Costs 350
Vessel Purchase 350
Swivels/Disconnect 350
Anchors 351
Materials Costs 352
Tanker Strengthening 352
Marine / Offloading 352
General Upgrade 352
Mooring Chain 352
Mooring Wire / Rope 353
Mooring Terminations 353
Frame / Mooring Arm 353
Turret / Riser 353
Chain table / Buoy 353
Riser Porch 353
Elevated Deck 354
Freight 354
Fabrication Costs 355
Tanker Strengthening 355
Marine / Offloading 355
General Upgrade 355
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Turret 355
Riser Porch 355
Elevated Deck 355
Installation Costs 357
Transport from fabrication yard 357
Mob / Demob and Tow out 357
Installation 357
Hook-up and Commissioning Costs 358
Sea Trials and Marine Commissioning 358
General Costs 359
Design 359
Project Management 359
Certification 360
Insurance 360
Contingency 360
About Cylindrical Hulls 361
Primary Inputs 362
Production Rate 362
Days of Storage 362
Required Storage 362
Topsides Operating Weight 363
Hull Weight 363
Water Depth 363
Distance to Installation Site 363
Marine Transport 363
Mooring System 364
Mooring Type 364
Anchor Type 365
Soil Condition 365
Environmental Conditions 366
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Mooring Chain Size 366
Number of Lines 367
Chain Length 367
Rope Length 367
Wire Length 367
Materials Costs 368
Hull Structure 368
Hull Outfitting and Marine Systems 368
Mooring Chains 368
Mooring Wire / Rope 368
Mooring Terminations 368
Anchors 369
Freight 369
Fabrication Costs 370
Hull Structure 370
Hull Outfitting and Marine Systems 370
Installation Costs 371
Transport from Fabrication Yard 371
Transport to Installation Site 371
Anchor and Mooring Installation 371
General Costs 372
Design 372
Project Management 372
Certification 373
Insurance 373
Contingency 373
About Tension Leg Platforms 374
Inputs 375
TLP Type 375
Topsides Operating Weight 375
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Water Depth 376
Number of Wells 376
Number of Pre-installed Risers 376
Soil Conditions 376
Environmental Conditions 376
Marine transport 377
Materials Costs 378
Hull 378
Foundations 378
Tendons 378
Tendon Connectors 379
Production Risers 379
Tensioning Equipment 379
Buoyancy 379
Freight 379
Fabrication Costs 380
Installation Costs 381
Transport from fabrication yard 381
Foundation Install 381
Transportation to installation site 381
Tendon Install 381
TLP Connect / Tension 381
General Costs 382
Design 382
Project Management 382
Certification 383
Insurance 383
Contingency 383
About Offshore Loading 384
Primary Inputs 385
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385
Loading Type 385
Water Depth 386
Export Rate 386
FlexiblePipeline 386
Number of Lines & Diameter 386
Riser Length at Buoy 386
Water Depth at Topsides 386
Riser Length at Topsides 387
Storage Tanker 387
Storage Time 387
Storage Capacity 387
Tanker Size 387
Marine transport 387
Mooring System 389
Mooring Type 389
Anchor Type 390
Soil Condition 390
Environmental Conditions 391
Mooring Chain Size 391
Number of Mooring Lines 392
Chain Length 392
Rope Length 392
Wire Length 392
Equipment Costs 393
Loading Buoy 393
Anchors 393
Storage Tanker 393
Materials Costs 394
Mooring Chain 394
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Mooring Wire / Rope 394
Mooring Terminations 394
Flexible Riser at Buoy 394
Riser System at Buoy 395
Pipeline (flexible) 395
Riser at Platform 395
Riser System at Platform 395
Installation Costs 396
Transport from fabrication yard 396
Tow out and installation 396
Sea trials and marine commissioning 396
General Costs 397
Design 397
Project Management 397
Certification 398
Insurance 398
Contingency 398
About Offshore Drilling 399
Inputs 400
Rig 401
Category 401
Profile 402
Well Details 402
Drilling Details 403
Water Depth 403
Reservoir Depth 403
Reservoir Pressure 403
Pressure Rating 403
Longest Stepout 403
Trip Speed 404
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Rate of Build 404
Acid Gas 404
Use ESPs 404
Drilling Profiles 405
Well Profile 406
Horizontal Section 406
Measured Depth and Deviation 408
Drilling/Completion Rig 409
Completion Type 409
Drilling Durations 410
Add Well / Remove Well 410
Drilling Curves 411
Rig class 411
Profile 411
Stage 411
Equipment Costs 413
Xmas trees 413
Wellheads 413
Completions 413
Electronic submersible pumps (ESP) 414
Exploration wellheads / Appraisal wellheads 414
Materials Costs 415
Drilling/Completion 415
Conductors 415
Drilling Template 416
Installation Costs 417
From Floating or Jackup 417
From Platform 418
Specialist Services 418
Transport 418
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Site Preparation 418
General Costs 420
Design 420
Project Management 420
Certification 421
Insurance 421
About Subsea 422
Inputs 423
Primary 425
Wells and Flowrates 425
Services 425
Layout 427
Item defaults 427
Flowline defaults 427
Features 429
Design conditions 429
HIPPS 430
Features 430
Tie-in Point 432
Flowlines 433
Lay Vessel 433
Flowline Type 434
Buried Lines 434
Material by Fluid Type 434
Thermal Insulation Material 435
Thermal Insulation U-value 435
PLET selection 436
Umbilicals 437
Control System 437
Control Tube Material 437
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Inhibitor Chemicals 437
Power Cables 437
Installation 439
Subsea Configuration 441
Item and Link Names 442
Item and Link Duplication 442
Subsea Items 446
General 446
Well details 447
Services 447
Multiphase metering 447
Umbilical Terminations 448
Subsea Flowlines 449
General 449
Well / Tie-back ends 449
Total flowrates 449
Flowline sizing 450
Coating and insulation 451
Well end termination / Tie-back end termination 452
Umbilicals 452
Subsea Tie-back 453
Tie-back type 453
Water Depth 453
Termination type 453
Sub-type 453
Riser Systems 454
Riser Length 454
Equipment Costs 455
Intervention Tools 455
Platform Controls Main 455
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Platform Controls Additional 455
Freight 455
Detailed Item Cost Breakdown 455
Main Structure 456
Xmas trees 456
Manifolding (Piping & Valves) 457
Multiphase metering 457
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Flowline Connectors/Pull-In 457
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Cluster Satellites 457
458
Control and Testing 458
HIPPS 458
Materials Costs 459
Riser Systems 459
Links 459
Umbilicals 460
Risers 461
Installation Costs 462
General Costs 463
Design 463
Project Management 463
Certification 464
Insurance 464
Contingency 464
About Barges 465
Developments with Barges 465
Primary Inputs 466
Storage Required 466
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Production Rate 466
Topside Operating Weight 466
Barge Size 466
Water Depth 467
Marine transport 467
Mooring System 468
Mooring Type 468
Anchor Type 469
Soil Condition 470
Environmental Conditions 470
Mooring Chain Size 470
Number of Lines 471
Chain Length 471
Rope Length 471
Wire Length 471
Equipment Costs 472
Barge Cost 472
Anchors 472
Materials Costs 473
Mooring Chain 473
Mooring Wire/Rope 473
Mooring Terminations 473
Freight 473
Installation Costs 474
Transport from fabrication yard 474
Tow Out and Installation 474
Sea Trials and Marine Commissioning 474
General Costs 475
Design 475
Project Management 475
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Certification 476
Insurance 476
Contingency 476
About Bridge Links 477
Inputs 478
Functions 478
Details 478
Process 479
Flow Type 479
Flowrates 480
Pressure 480
Diameter 480
Materials Costs 481
Primary Steel 481
Secondary Steel 481
Piping 481
Electrical Bulks 481
Instrument Bulks 482
Others 482
Freight 482
Fabrication Costs 483
Loadout and Seafasten 483
Installation Costs 484
Tugs Transport Spread 484
Barge Transport Spread 484
Installation Spread 484
General Costs 485
Design 485
Project Management 485
Certification 486
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Insurance 486
Contingency 486
About User Defined 487
Cost Estimate 488
Operating Expenditure - OPEX 489
Working with OPEX 490
Locking/Unlocking 491
Applying a Change to a Range of Cells 492
Operating Personnel 494
Inspection and Maintenance 495
Platforms 495
Pipelines 496
Power Cables 496
Subsea 497
Logistics and Consumables 498
Helicopters 498
Supply Boats 498
Rescue and Recovery Boat 498
Fuel Gas 498
Diesel 499
Chemicals 499
Well Costs 500
Insurance 501
Field / Project Costs 502
Tariffs 503
CO2 Emission Taxes 504
Leases 505
Capital Expenditure Scheduling 506
CAPEX Scheduling Window 507
Distributions 508
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Intra-component Relationships 509
Inter-component Relationships 510
Locking 510
First Oil 510
Timescale 511
Adding and Removing Components 511
CAPEX Breakdown Graphs 512
About Decommissioning 513
Decommissioning Scenarios 514
Decommissioning duration 514
Delay after end of field life 514
Component Decommissioning 515
Cost estimate 515
Scrap 515
Inputs 516
Distance to Disposal Site 516
Temporary Piping Weight 516
Padeyes Weight 516
Crane Size 516
Maximum Lift Weight 517
Number of Lifts 517
Weights 518
Hazardous Volumes 519
Flushing / Inerting 520
Flushing Days 520
Inerting Days 520
Dismantle / Removal 521
Cost Sheet 522
Materials 522
Fabrication 523
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Decommissioning / removal 523
Design and Project management 524
Insurance 524
Certification 524
Contingency 525
Scrap 525
Inputs 526
Removal 526
Disposal 526
Lifts 527
Details 528
Jacket 528
Attachments 528
Cost Sheet 529
Materials 529
Fabrication 530
Decommissioning / removal 530
Design and Project Management 531
Insurance 531
Certification 531
Contingency 531
Scrap 532
Pipeline Decommissioning 533
Removal 533
Disposal 533
Cleaning 534
Details 535
Pipeline Decommissioning Cost Sheet 536
Decommissioning / Removal 536
Design and Project Management 537
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Insurance 538
Certification 538
Contingency 538
Scrap 538
About the Investment and Production Profile 539
Exporting the Investment Profile into AS$ET 541
QUE$TOR Structure 542
Once on the FDS 543
About Project Properties 544
Units of Measure 545
Main Product 545
Location 545
Creating Procurement Strategies 547
To create a new procurement strategy 547
About Field Level Data 549
Field Characteristics 550
Fluid / Profile Characteristics 552
Liquid Data 552
Gas Data @ STP 552
Well Data 553
Miscellaneous 554
Miscellaneous Items 554
Layout 554
Artificial Lift 555
Temperature 555
BOEEquivalents 555
About Production Profiles 556
Production Profile Edit 557
Production Profile 558
Design Flowrates 560
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Peak daily average production rates 560
Design rates 560
Water injection 561
Gas injection 561
Gas lift 561
Number of Wells 562
Wellhead Conditions 563
About the Concept Selector 564
Concept Selection for New Projects 565
Concept Selection for Existing Projects 567
Field Development Schematic 569
Pipelines & Linking Components 570
About Component Level Data 572
Cost Summary Tree 572
Component Toolbar 574
Component Duplication 576
Well and Flow Distribution 579
Onshore Cost Centres 581
Equipment Costs 581
Materials Costs 581
Prefabrication Costs 583
Construction Costs 583
Design and Project Management Costs 584
Insurance and Certification Costs 585
Contingency 585
About Onshore Components 586
Cost Summary Tree 586
Input Panel 586
Cost Estimate Sheets 587
About Production Facilities 588
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User Interface 589
Inputs 589
Facilities 590
Cost Estimate 591
Primary Inputs 592
Terrain 592
Elevation 592
Functions 592
Capacities 593
Fluid Capacities 594
Inlet High Pressure Fluids 594
Arrival Temperature 594
Arrival Pressure 594
Well Stream Fluids 594
Separated Fluids 595
Inlet Medium Pressure Fluids 595
Total Capacities 595
Design Conditions 596
Reservoir Pressure 596
Acid gas / High T / High P 596
Max. Ambient Air Temperature 596
Prefabrication 597
Winterisation 598
598
Manifolding 599
Number of Flowlines 599
Multiphase metering 599
Operating Pressure 600
Design Pressure 600
Weight 600
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Oil Processing 602
Oil Processing Configurations 602
Stream Properties 603
Equipment Sizing 604
Gas Processing 607
Cooling 608
Acid Gas Removal 608
Membrane Unit 608
Conventional Acid Gas Removal 609
Sulphur 611
Dehydration 612
Dewpoint Control 613
Gas Metering 614
Deethaniser 614
Stabiliser 614
Produced Water 616
Product Storage 617
Atmospheric Storage Inputs 617
Pressurised Storage Inputs 618
Product Export 620
Export Rate 620
Size Export Pipeline 621
Details 621
Driver 622
Derating Factor 622
Capacity 622
Driver Model 622
Pump Weight 623
Pump Driver Weight 623
Metering Capacity 623
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Metering Weight 623
Gas Compression 624
Compressor Classification and Selection 624
Flash gas 624
Export gas 625
Gas lift 625
Gas injection 625
Compressor Sizing 625
Compressor type 625
Number of stages 626
Power 626
Derated power 626
Number of compressors 626
Design duty/compressor 626
Driver type 626
Driver model 627
Driver rating 627
Pipeline Sizing 627
Coolers 628
Weights 628
Water Injection 629
Details 629
Driver 630
Configuration 631
Weight 631
Custom Equipment 632
General 634
Bulk materials, utilities and operating weight 634
Utilities 634
Power 634
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Civils 634
Cost sheet 635
Example 635
Cost sheet 636
Custom equipment library 637
637
Control and Communications 638
Control System 638
Communications 638
Process Utilities 640
Process Support Utilities 640
General Utilities 641
Power 643
Power Requirement 643
Emergency Power 644
Generation and Distribution / Distribution only Radio Buttons 644
Derating Factor 644
Capacity 645
Driver 645
Weights 646
Civils 647
Foundation Area 647
Plot Area 648
Equipment List 649
Equipment Costs 651
Freight 651
Material Costs 652
Steelwork 652
Piping 652
Electrical 652
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Instruments 653
Others 653
Civils Materials 653
Freight 653
Prefabrication Costs 654
Loadout and Transport 654
Construction Costs 655
Site Preparation 655
Civil Construction 655
General Costs 656
Design & Project Management 656
Insurance 657
Certification 657
Contingency 657
About Terminal Facilities 658
User Interface 659
Inputs 659
Facilities 660
Cost estimate 660
Primary Inputs 661
Location 661
Inlet Flows 661
Export Method 662
Marine Transport 662
Prefabrication 663
Winterisation 664
Product Storage 665
Atmospheric Storage Inputs 665
Pressurised Storage Inputs 666
Product Export 668
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Export Rate 668
Size Export Pipeline 668
Details 669
Driver 669
Derating Factor 669
Capacity 669
Driver Model 670
Pump Weight 670
Pump Driver Weight 670
Metering Capacity 670
Metering Weight 670
Control and Communications 671
Control System 671
Communications 671
Process Utilities 673
Process Support Utilities 673
General Utilities 674
Power 675
Generation and Distribution / Distribution only Radio Buttons 675
Power Requirement 676
Emergency Power 676
Derating Factor 676
Duty 676
Driver 677
Weights 677
Civils 679
Foundation Area 679
Plot Area 680
Equipment Costs 681
Product Loading 681
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Safety 682
Freight 682
Material Costs 683
Steelwork 683
Piping 683
Electrical 683
Instruments 684
Others 684
Offloading Buoy (marine) 684
Offloading Pipeline 684
Jetty Materials 684
Civils Materials 684
Freight 684
Prefabrication Costs 685
Loadout and Transport 685
Construction Costs 686
Site Preparation 686
Civil Construction 686
Buoy Installation 686
Pipeline Installation 686
Jetty Construction 687
General Costs 688
Design & Project Management 688
Insurance 689
Certification 689
Contingency 689
About Onshore Pipelines 690
Pipeline Links 691
Length 691
Flow Type 691
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To / From 692
Pipeline Sizing 694
For oil, gas, liquid & two phase lines 695
For gas injection, gas lift and water injection lines 695
Material 695
Oil / Gasoline/Condensate / NGL / LPG 696
Water Flowrate 696
Gas Flowrate 696
Fluid Temperature 696
Pipeline Sections 697
Nominal Diameter 697
Fixed Diameter 697
Corrosion Allowance 697
Wall Thickness 697
Slug Catchers 699
Winterisation 700
Pipeline winterisation 700
Booster station winterisation 700
Pipeline Sections 701
Pipeline Sections 702
Booster / Reducer Stations 703
Booster / Reducer Stations 705
Product Export / Gas Compression 705
Control and Communications 707
Utilities 708
Power 709
Generation and Distribution / Distribution only Radio Buttons 710
Power Requirements 710
Emergency Power 710
Derating Factor 711
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Duty 711
Driver 711
Weights 712
Civils 712
Terrain and Crossings 714
Terrain Type 714
Construction Type 714
Length 714
Number of Crossings 714
Construction Duration 715
Pipeline Schematic 716
Construction Duration 717
Equipment Costs 718
Booster Stations 718
Reducer Stations 719
Slug Catchers 719
Freight 719
Materials Costs 720
Linepipe 720
Fittings 720
Coatings 720
Crossings 720
Civils Materials 721
Booster Stations 721
Slug Catchers 722
Freight 723
Construction Costs 724
Booster Stations 724
Slug Catchers 725
General Costs 726
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Design & Project Management 726
Insurance 727
Certification 727
Contingency 727
About Wellpad Groups 728
User Interface 729
Inputs 729
Primary Inputs 731
Location 731
Wells 731
Prefabrication 733
Winterisation 734
Wellpad Editor 735
Wellpad Editor Primary Inputs 737
Linkages 737
Equipment 737
Multiphase meters 737
Power Requirements 738
Well Count 738
Wellpad Editor Flowline Bundle 739
Bundle 739
Flowlines 740
Construction 740
Number of Crossings 741
Wellpad Editor - Details 742
Manifolding and Equipment 742
Utilities 742
Power 742
Flowlines 743
Flowline 743
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Installation 744
Control System 745
Civils 746
Equipment Costs 747
Manifolding 747
Multiphase Metering 747
Freight 747
Materials Costs 749
Steelwork 749
Piping 749
Electrical 749
Instruments 750
Others 750
Flowlines 750
Umbilical 750
Power Cable 750
Crossings 750
Civils Materials 750
Freight 751
Prefabrication Costs 752
Loadout and Transport 752
Construction Costs 753
Site Preparation 753
Civil Construction 753
Flowline Testing 753
Flowline Right of Way 753
General Costs 755
Design & Project Management 755
Insurance 756
Certification 756
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Contingency 756
About Onshore Drilling 757
User Interface 758
Inputs 758
Details 760
Rig Class 760
Well Type 761
Pumped Wells 761
Profile 762
Well Details 762
Drilling Details 763
Winterisation 765
Winterisation Cost 765
Drilling Profiles 766
Well Type 767
TVD 768
Kick Off 768
Horizontal Shift 768
Profile Type 768
Horizontal Section 768
Measured Depth 770
Maximum Deviation 771
Drilling Rig 771
Completion Rig 771
Completion Type 771
Drilling Durations 772
772
Drilling Curves 773
Rig class 773
Profile 773
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Stage 774
Equipment Costs 776
Xmas trees 776
Wellheads 776
Completions 776
Exploration wellheads / Appraisal wellheads 777
Pumps 777
Freight 777
Material Costs 778
Cement 778
Mud 778
Brine 778
Bits 779
Freight 779
Construction Costs 780
Rig Hire 780
Drill Crew 780
Consumables 780
Drill Camps 781
Transportation 781
In-field Rig Down / Relocation / Rig up 781
Mob / Demob 781
Drilling Services 781
Other Costs 782
General Costs 783
Design & Project Management 783
Insurance 784
Certification 784
Contingency 784
About Infrastructure 785
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User Interface 786
Inputs 786
Facilities 787
Cost Estimate 787
Primary Inputs 788
Location 788
Distances to Major Populations 788
Road 790
Road Links 790
Road Type 791
Terrain 791
Rail 792
Terrain 793
Construction Camp 794
Operations Camp 795
Administration Offices 796
Permanent Housing 797
Medical / Hospital Facilities 798
Schools, Places of Worship, Community Buildings 799
Power Transmission 800
Airstrip 801
Material and Construction Costs 802
Road Construction 802
Rail Construction 803
Construction Camp 803
Operations Camp 803
Administration Buildings 803
Permanent Housing 803
Medical Facilities 803
Schools, Places of Worship 803
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Power Transmission 804
Airstrips 804
Community Projects/Others 804
General Costs 805
Design & Project Management 805
Insurance 806
Certification 806
Contingency 806
About User Defined Components 807
Cost Estimate 808
Operating Expenditure - OPEX 810
Working with OPEX 811
Locking/Unlocking 812
Applying a Change to a Range of Cells 813
Operating Personnel 814
Inspection and Maintenance 815
Logistics and Consumables 816
Fuel Gas 816
Diesel 816
Chemicals 817
Transportation 817
Messing 817
Vehicles 818
Well Costs 819
Insurance 820
Field / Project Costs 821
Support 821
Land Costs 821
Tariffs 823
CO2 Emission Taxes 824
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Lease costs 825
Capital Expenditure Scheduling 826
CAPEX Scheduling Window 827
Distributions 828
Intra-component Relationships 829
Inter-component Relationships 830
Locking 830
First Oil 831
Timescale 831
Adding and Removing Components 831
CAPEX Breakdown Graphs 832
About Decommissioning 833
Decommissioning Scenarios 834
Decommissioning duration 834
Delay after end of field life 834
Component Decommissioning 835
Cost estimate 835
Scrap 835
About the Investment and Production Profile 836
Exporting the Investment Profile into AS$ET 838
LNG Regasification Structure 839
About Regasification Terminal Facilities 840
User Interface 841
Inputs 841
Facilities 842
Cost estimate 842
Primary Inputs 844
Terrain 844
Elevation 844
Functions 844
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Capacities 845
Inlet Composition 846
Molecular weight 846
Composition 846
Gas Properties 847
Design Specifications 848
Sales gas specification 848
Maximum ambient air temperature 848
Prefabrication 849
Winterisation 850
Marine Infrastructure 851
Ship / Berth Details 851
Jetty details 852
Marine Slip Details 852
LNG Metering 853
LNG Flowlines / Berth 853
Breakwater 854
Dredging 854
LNG Storage 855
Containment Type 855
Number of Tanks / Capacity per Tank 856
Diameter / Height 856
LNG Processing 857
Nitrogen injection 858
Demethaniser 859
Deethaniser 860
Stabiliser 860
Stream properties 860
861
LNG Pumping 862
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In-tank Pumps / Tank 862
LNG Processing Feed Pumps 863
Send out Pumps 863
Liquid Storage 865
Atmospheric Storage Inputs 865
Pressurised Storage Inputs 866
Liquid Export 868
Export Rate 869
Size Export Pipeline 869
Details 869
Driver 870
Derating Factor 870
Capacity 870
Driver Model 871
Pump Weight 871
Pump Driver Weight 871
Metering Capacity 871
Metering Weight 871
Vapour Handling 872
Derating Factor 872
Boil off Gas Compression (BOG) 873
Recondenser 874
Vapour Return Blowers 874
Vapourisation 876
Process 876
Open Rack 877
Submerged Combustion 878
Intermediate Fluid 878
Gas Metering 879
Control and Communications 880
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Control System 880
Communications 880
Process Utilities 882
Process Support Utilities 882
General Utilities 883
Power 885
Power Requirement 885
Generation and Distribution / Distribution only Radio Buttons 886
Derating Factor 886
Duty 886
Driver 887
Emergency Power 887
Weights 888
Civils 889
Foundation Area 889
Totals 890
Equipment Costs 891
Odourisation 891
Safety 891
Freight 892
Material Costs 893
Steelwork 893
Berth 893
Jetty 893
Marine Slip 893
Breakwater 894
LNG Flowlines 894
Piping (cryogenic) 894
Piping 894
Electrical 894
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Instruments 894
Others 894
Civils Materials 895
Freight 895
Prefabrication Costs 896
Loadout and Transport 896
Construction Costs 897
Site Preparation 897
Civil Construction 897
Tank Excavation 897
General Costs 898
Design & Project Management 898
Insurance 899
Certification 899
Contingency 899
Operating Expenditure - OPEX 900
Working with OPEX 901
Locking/Unlocking 902
Applying a Change to a Range of Cells 903
Operating Personnel 905
Inspection and Maintenance 906
Logistics and Consumables 907
Nitrogen 907
Fuel Gas 907
Diesel 907
Transportation 908
Messing 908
Vehicles 908
Insurance 910
Field / Project OPEX 911
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Support 911
Land Costs 911
Tariffs 913
CO2 Emission Taxes 914
Leases 915
Capital Expenditure Scheduling 916
CAPEX Scheduling Window 917
Distributions 918
Locking 919
First Oil 919
Timescale 920
Adding and Removing Components 920
CAPEX Breakdown Graphs 921
Investment and Production Profile 922
Exporting the Investment Profile into AS$ET 924
About Decommissioning 925
Decommissioning Scenarios 926
Decommissioning duration 926
Delay after end of field life 926
Component Decommissioning 928
Cost estimate 928
Scrap 928
Data Input 929
Text boxes 929
Option buttons 929
Dropdown lists 929
Check boxes 930
Locked Values 931
To Unlock a Locked Value 931
Units 932
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Unit Nomenclature 932
Form Conventions 933
Tabs 933
Form Buttons 933
Component buttons 933
Warning Messages 935
About Program Menus 936
File Menu 937
Project Menu 938
Options Menu 939
Reports Menu 940
Tools Menu 942
Help Menu 943
About Data Flow and Locking 944
Data Flow between Components 945
Exceptions to the hierarchy order 947
Multiple topsides 947
Data Flow Within Components 948
Locking 949
About Project Costs 950
Project Cost Options 951
To add a project cost 951
To remove a project cost 952
To set the default project costs 953
Managing Project Costs 954
Item name 954
Cost 954
Schedule distribution 954
Schedule duration 955
Creating a new project cost 955
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Deleting a project cost 956
About Contingency 957
Base Cost Estimate 957
Expected Value (or most likely cost) 957
Contingency 957
Accuracy Levels 958
Operators Reserve 958
Contingency Options 960
About Component Ghosting 962
Ghosting of Components 963
Ghost CAPEX 963
Ghost OPEX 964
Ghosting Options 965
About Decommissioning 966
About Reports 967
Component Reports 969
Project Reports 970
Locked Values 972
Project Notes 974
About Database Editor 976
Procurement Strategies 977
View/Edit Procurement Strategy 977
Technical Databases 979
View/Edit Technical Database 979
Database Editor Interface 981
Item Type (procurement strategies) 981
Item Type (technical databases) 981
Component Type 982
Table Description 982
About Project Editor 985
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User Interface 986
To Change a Procurement Strategy or Technical Database 986
Procurement Strategies 988
Technical Databases 989
About Project Viewer 991
User Interface 993
Exporting from the Project Viewer 995
About Unit Editor 996
Custom Unit Sets 997
About Network Licences 1000
Feature 1000
Days until expiry 1000
Borrowed until 1000
Network Licence Management 1001
To borrow a feature from the network licence server 1001
To return a feature to the network licence server 1001
Restrictions 1002
ANSI Pressure Ratings 1003
Flow Definitions 1004
Basis of Inspection and Maintenance 1005
Comparison of Profile Timescales 1006
Offshore Components 1007
Offshore Concepts 1010
Decommissioning Toolbar 1011
Fabrication Details 1012
Installation Vessel Maximum Lift Weights 1014
CAPEX Scheduling Toolbar 1015
Offshore Technical Databases 1016
Offshore Toolbar 1017
Barge Sizes With Storage 1018
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Barge Sizes Without Storage 1019
Offshore Casing / Tubing Programme 1020
Offshore Drilling Profiles 1021
Concept Selector - Export Options 1022
CO2 Removal Only 1023
H2S Removal Only 1024
Simultaneous H2S and CO2 Removal 1025
Solvent Data 1026
Typical Gas Compositions 1027
Default Dehydration Process 1028
GBS Storage Capacity 1029
Jacket Installation Factors 1030
Maximum Topsides Weight 1031
Monotower GBS Concrete Volume 1032
Semi-submersible Characteristics 1033
Maximum Load and Buoyancy Aid Weights 1034
Subsea Flexible Flowline Limits 1035
Flying Leads Calculation 1036
Subsea Pressure Ratings 1037
Subsea Toolbar 1038
Standard Chain and Rope Sizes 1039
Wind Speed Lookup 1040
Single Point Mooring Systems 1041
Tanker Storage Capacity 1042
Offshore Gas Processing Product Specification 1043
Oil Processing Defaults for Gas Projects 1044
Oil Processing Defaults for Oil Projects 1045
Oil Processing Toolbar 1046
Tripod GBS Concrete Volume 1047
Basis of Inspection and Maintenance 1048
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Onshore Components 1049
Onshore Concepts 1050
Construction Details 1051
Prefabrication Details 1053
Onshore Technical Databases 1055
Onshore Toolbar 1056
Onshore Drilling - Profiles 1057
Onshore Drilling - Rig Class 1058
Default Dehydration Process 1059
Onshore Casing / Tubing Programme 1060
Solvent Data 1061
CO2 Removal Only 1062
H2S Removal Only 1063
Simultaneous H2S and CO2 Removal 1064
Typical Gas Compositions 1065
Gas Processing Defaults 1066
Column Operating Conditions - Single Column 1067
Column Operating Conditions - Both Columns 1068
Oil Processing Defaults for Gas Projects 1069
Oil Processing Defaults for Oil Projects 1070
GRP Pipe Sizes 1071
Basis of Inspection and Maintenance 1072
Double Containment LNG Storage Tanks 1073
Full Containment LNG Storage Tanks 1074
Single Containment LNG Storage Tanks 1075
LNG Tanker Properties 1076
LNG Regasification Onshore Toolbar 1077
Comparison of Profile Timescales 1078
Database Editor Toolbar 1079
Project Viewer Toolbar 1080
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Unit Sets 1081
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About the Quick Start GuideThis guide is designed to help you understand the operation of the QUE$TOR program,outlining the basic steps involved in developing a QUE$TOR project to produce ascheduled estimate for capital and operating costs.
QUE$TOR is structured around a field development schematic (FDS) which allows youto create a visualisation of the development. The FDS is driven by a number of highlevel inputs which allow the development conditions to be specified. The basicprogram calculation sequence followed in QUE$TOR to generate a full life-cycle fieldor prospect development cost estimate is shown below.
To define the new project, QUE$TOR presents you with a series of forms that allowhigh level parameters of the development to be specified.The Field level data form ispopulated with default values for the basin selected in the Project properties form.Subsequent forms have values and selections based on earlier entries. Once you
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have reviewed and adjusted as necessary the default inputs in each form, click on OKto apply the inputs and move on to the next form.Click on Cancel to ignore changesmade and go back to the previous form and make any necessary revisions.
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Getting StartedQUE$TOR must be installed on a local PC. This must be done by a local administrator.See the release notes for installation instructions.
QUE$TOR will run on these following operating systems:
Windows XP Windows Vista Windows 7 Windows 8.
A licence must be available; either a standalone dongle which plugs directly into yourcomputer or a network licence which is accessible across your company's local areanetwork. QUE$TOR Offshore, QUE$TOR Onshore and QUE$TOR LNG Regasificationrequire separate licences. Contact your IT department for further details.
Depending on your installation options, you can launch QUE$TOR either from thetaskbar Start button or from your PC desktop.
From the taskbar Start button
Click Start and follow All Programs\IHS\QUE$TOR 2014 Q3
From your PC desktop
Double-click the QUE$TOR 2014 Q3 application shortcut icon .
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Creating a New ProjectOn opening QUE$TOR the task selection form will appear.
On this form you can choose to create a new project or open an existing project. Fornew projects you can either create a new offshore project or a new onshore project.For existing projects there are shortcuts to the last five projects saved.
The location of your wells should determine whether you pick offshore or onshore asthe start point. If you are running a combined offshore and onshore project then thesecond location can be selected later in the project estimate.
Once you have selected your project location i.e. offshore or onshore, click OK tomove onto the Project properties form. QUE$TOR will check that you have a validlicence to run the selected project type at this point.
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Selecting the Project PropertiesThe project properties allow you to setup the basic information about your projectincluding the procurement strategy, regional technical database and units setpreference.
Work through the following steps to set up your project:
l Give your project a name.
l Select the units you want to work in.Pick from one of the standard unit setsprovided or create your own using the Unit editor tool. For the majority of users
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one of the default unit sets should meet your needs as you can change each unit asneeded throughout the program.
l Select the main product. For Oil projects you will have to define your recoverableoil reserves and a gas oil ratio, while for gas projects you will input yourrecoverable gas reserves and a liquid gas ratio.
l Select the geographical region, country, and basin to enable QUE$TOR to seedyour project with typical basin specific data generated from the IHS IRIS21 E&Pdatabase. This selection will also drive the default location of a new procurementstrategy and will set your regional technical database.
l Create your procurement strategy. This can be done by clicking the Newbutton.This will display the Define procurement strategy form shown below. Procurementstrategies allow you to choose different regional cost databases for each costcentre. By default all costs are reported in US Dollars but this can be edited bychanging the currency name, symbol and exchange rate at the top of the form.
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l Select the technical database to use for your project. This will normally be theregion which you have selected for your project.Use Browse to select analternative if required.
Once you have completed the above steps, click OK to move onto the Field level dataform.
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Entering Your Field Level DataThe Field level data form contains three tabs which list the values for the fieldcharacteristics, fluid characteristics and some miscellaneous data respectively.
The information entered varies slightly depending on whether you have selected anoffshore or onshore project. Default values are populated from a database relevantto the basin you selected in the Project properties form.
On this form, modify the data to the specifics of the field that you want to produce anestimate for. The purpose of the default data is to provide a reasonable value wherenone is known and therefore you should use your values over these defaults. Anyinput value can be changed by simply over-typing it.
In this form, and any other form, the individual input units can be changed on the flyby clicking on the unit to the right of the value and selecting the unit you wish to usefrom the options available, this is shown for the recoverable reserves input below.
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Once you have entered / confirmed the data on all three tabs click OK to move ontothe Production profile edit form.
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Creating a Production ProfileThe production profile is created through two forms; the first form gives sevenentries through which you can influence the basic parameters of your productionprofile.
Enter any of the values you know at this point and then click OK to move onto theProduction profile form which gives you a visual representation of these values.
The production profile is displayed in a graphical and tabular format across four tabs;oil (or condensate), gas, water and gross liquids. Numbers in blue can be edited;numbers in black such as those in the gross liquids tab are derived numbers andtherefore cant be edited. This colour convention is common throughout QUE$TOR.
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You can change the production for each year by entering the values in the table at thebottom of the form. This can either be typed in year by year or you can paste in aprofile from an external spreadsheet through a right mouse click. You can overwriteeither the daily or annual flowrates but not the cumulative row of the table. You canalso copy the data in the production profile and paste it into an external spreadsheet.
Note: When pasting in a production profile from a spreadsheet ensure that thefield life specified in the production profile edit form is the same as that of the profileyou are pasting in.
Once you are happy with the production profile, click OK to move onto the Designflowrates form.
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Setting the Design FlowratesThe Design flowrates form gives the flowrates that will be used to design the facilitieswithin your project.
The production values are based on the peak production with a design factor for oilprojects giving an allowance for day to day variation, and a swing factor in gasprojects giving an allowance for seasonal demand variation.
The injection values should be adjusted based on your pressure maintenance and gasdisposal assumptions.
Once you are happy with the design flowrates, click OK to move onto the Number ofwells form.
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Setting the Number of WellsThe Number of wells form, shown below, sets the total number of wells requiredacross the field.
The default number of production wells is based on the recoverable reserves, wellproductivity, plateau production and peak well flow. The default number of waterinjection wells assumes an average of two injectors for every five oil productionwells.Gas injectors are based on an average flowrate of 30 MMscf/day per well.
Modify the well count to match your design assumptions and click OK to move ontothe Wellhead conditions form for onshore projects or the Concept selector form foroffshore projects.
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Setting the Wellhead ConditionsThe Wellhead conditions form is only available for onshore projects and provides thewellhead conditions of the primary streams.
Water injection, gas injection and gas lift pressure are only relevant if these servicesare selected. Adjust the conditions as necessary and then click OK to move onto theConcept selector form.
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Selecting a Concept - OffshoreThe Concept selector form allows you to choose the basic concept of your fielddevelopment.
QUE$TOR selects a field development concept based on the field level data andproduction profile.You can change this to another of the 14 default concepts using thelist box. If you want to configure your concept from scratch, select 'Blank concept'.
Based on your concept, QUE$TOR will select typical oil and gas export options. Adjustthese to match your desired product export routes.
When you click OK QUE$TOR runs the complete cost estimate using program defaultsthroughout and displays the field development schematic along with the costsummary tree.
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Selecting a Concept - OnshoreThe Concept selector form allows you to choose the basic concept of your fielddevelopment.
QUE$TOR selects a field development concept based on the field level data andproduction profile.You can change this to another of the 6 default concepts using thelist box. If you want to configure your concept from scratch, select 'Blank concept'.
Based on your concept, QUE$TOR will select typical oil and gas export options. Adjustthese to match your desired product export routes.
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When you click OK QUE$TOR runs the complete cost estimate using program defaultsthroughout and displays the field development schematic along with the costsummary tree.
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Using the Field Development SchematicOn selecting your concept and clicking OK QUE$TOR will move through to the mainfield development schematic.
The field development schematic shows the components within your chosen concepton the right hand side of the screen, with the associated high level CAPEX summaryon the left hand side of the screen.
The schematic can be changed by adding and removing components. You can selectcomponents to add from the component toolbar at the top of the screen and click onthe schematic to place the component. To delete a component hit delete when thecomponent is selected or right click on the component and select Delete. You will beasked to confirm any deletions to prevent any components being inadvertentlydeleted.
Components often require links so that the correct data can flow between them.
Components are linked using the link icon in the toolbar . Once you have linkedtwo components you may need to add a pipeline by double clicking on the link.
Note: Connections from drilling components, subsea, and wellpad groups do notrequire pipelines to be specified.
Each component will be estimated using default assumptions based on the data youhave entered so far. To view a component in detail you can double click on it or rightclick on it and select Edit / view cost estimate.
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Adjusting a ComponentYou can view the details of each component by either double clicking on thecomponent or by right clicking and selecting Edit / view cost estimate.
Each component has two main parts to it: the inputs, where you can adjust the designparameters, and the cost sheet, where you can see the detailed breakdown of thecost.
You can make changes within each of these areas and when you click Apply or OKthese changes will be applied to the component and the CAPEX estimate adjustedaccordingly. Clicking on OK will also exit the component. Clicking Cancel also exitsthe component; however you will lose all changes made since you entered thecomponent.
Inputs
The left hand side of the screen contains the main input data for that component. Theinput form for the topsides component is shown below.
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The input form shows the main design parameters for a given component, such as thedesign flowrates. You can make changes to these values to match your designassumptions. When you click Apply these changes will be applied to the componentand the CAPEX estimate adjusted accordingly.
Sub-components
There are arrow buttons within many components that can be clicked on to openup one of the sub-components; the details of that system are then shown. Thetopsides Manifolding sub-component form is shown below.
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You can make changes within each sub-component and when you click OK thesechanges will be applied to the component and the CAPEX estimate adjustedaccordingly.
Cost sheet
The right hand side of the screen has the cost sheet. This shows a detailed breakdownof the CAPEX estimate for the component. Each line item is made up of a quantity anda unit rate.
The quantity is calculated from the design parameters and technical algorithms forthat item and the unit rate is taken from the selected procurement strategy. You canoverwrite any of the blue values within the cost sheet, as shown for the quantityentry above. Numbers in black are derived by multiplying the quantity by the unitrate so cant be overwritten.
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Calculating the Operating CostsThe operating cost calculations should be run once you have finished the design ofyour development as the costs are based on the technical definition of thedevelopment.
The OPEX algorithms are run by selecting OPEX from the Project menu. This willopen a separate window where a summary of the operating costs for each year ofproduction is displayed.
The costs are broken down into various categories, which can be seen on the left sideof the screen. The detailed breakdown of these cost categories can be seen byclicking on these items, they are formatted as blue hypertext. This will open upfurther definition sheets for you to review or adjust the default values.
Once you are happy with the operating costs, click OK to go back to fielddevelopment schematic so that you can generate the project schedule.
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Scheduling the Capital CostsThe CAPEX scheduling calculations should be run once you have finished the design ofyour development as the schedule and costs are based on the details of thedevelopment.
The CAPEX scheduling module can be accessed by selecting Scheduling from theProject menu. The schedule will be shown as a Gantt chart along with the underlyingdata for each component.
For each component, a detailed schedule can be viewed by expanding the component
using the icon. You can adjust the start date and activity duration either bydragging the bars within the Gantt chart or by adjusting the corresponding values inthe table. Adjusting these values will change when the calculated CAPEX values are tobe spent.
Once you are happy with the project schedule, click OK to go back to fielddevelopment schematic so that you can generate the Investment and productionprofile.
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Generating the Investment and Production ProfileThe investment and production profile is run by selecting Investment andproduction profiles from the Project menu.
The investment and production profile gives a report of all of the values that could berequired to run an economic analysis, with the production, CAPEX and OPEX given foreach year of the project. The values in this report are in real terms, i.e. they arecosts specific to a particular point in time (depending on the version) and have notbeen inflated or discounted over the life of the project.
This report can be printed or exported to Excel using the toolbar buttons.
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Saving Your ProjectProjects are not automatically saved in QUE$TOR. We recommend you save yourproject when you reach the field development schematic and at regular intervalsafter this.
To save a project select Save or Save As from the File menu or click on the Save
project button . This will enable you to save the project in the usual Windowsfashion. The default location for saved projects is MyDocuments\IHS\QUE$TOR\Projects.
Saved project files have a .qpr file extension and include the selected procurementstrategy, technical database and unit set. Once saved, projects are completelystandalone and have no further interaction with QUE$TORs databases. This meansthat saved projects can easily be sent to others who may not have the samedatabases.
Saved projects can be moved, copied and renamed using Microsoft Windows Explorerin the same way as any Windows file. Projects can be opened either directly fromWindows Explorer or from within QUE$TOR. To open a saved project in QUE$TOReither select Open existing project from the form that appears when QUE$TORstarts or select Open from the File menu.
Note: When you create a new project you won't be able to save the project untilyou reach the field development schematic.
Opening a Saved Project
To open a saved project select, using the option buttons, Browse for project and
click OK to proceed or click on the Open project button .This will enable you toopen a project in the usual windows fashion.The Open existing project box hasshortcuts to the last five projects opened in QUE$TOR.Saved projects have a .qprfile extension.
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About QUE$TORQUE$TOR has been designed to produce high level estimates of the capital andoperating costs of green field oil and gas developments. It will assist with projectmodelling, evaluation and subsequent decision making in the oil and gas industry.
QUE$TOR provides a reliable, consistent methodology for producing cost estimatesand creates efficiency when optimising field developments. It has benefits in manyapplications, including:
l Prospect evaluations
l Screening studies
l Feasibility studies
l Conceptual studies
l Optimisation studies
QUE$TOR uses a systematic approach to generate a field development basis, capitaland operating costs, and project schedules from basic field data. QUE$TOR uses abottom up methodology; the calculations are based around detailed sizing algorithmsand engineering rules of thumb with regional variations where appropriate.
This approach allows engineers, estimators and economists to produce weight andcost estimates quickly, consistently and accurately and to develop investmentprofiles.
Capabilities
QUE$TOR has the capability to handle most oil and gas developments worldwide, ithas clearly defined methodologies for offshore and onshore upstream developmentsas well as onshore LNG regasification projects. Any combination of these threeproject types can be modelled provided you have the requisite licences.
In generating capital cost estimates for a field development, the estimate is brokendown into a number of discrete components.Combining these components allows afield development plan to be identified and estimated.It is then possible to generateoperating costs for the facilities specified and phase the expenditures as necessary.
The use of separate cost and technical databases for all major worldwide oil and gasproducing regions means that any development, present or future, can be modelled.
Cost Databases
There are 17 offshore and 11 onshore regional cost databases behind the program.These cost databases are updated on a six-monthly basis with a new version of theprogram sent out for each update. Each new version can be installed alongside allexisting versions of the program allowing you to track costs of a project over time.
Each of the databases is editable meaning that if there is a region where you have agood understanding of the costs you can overwrite some of the costs within theQUE$TOR databases to give you greater confidence in the estimate.
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Estimate BasisThe following points should be considered when generating or reporting a costestimate using QUE$TOR.
l QUE$TOR provides an estimate based on the costs within the markets today. Wemake no allowance for inflation or deflation of costs over the project life.
l All of the costs within QUE$TOR are in real terms, i.e. they are costs specific to aparticular point in time (depending on the version). We do not apply anydiscounting or inflation to the estimate to costs incurred over the project life.
l Pre-sanction costs, such as FEED studies and environmental impact assessments,are not included within the estimate by default. These costs can be optionallyadded as a percentage of the project CAPEX costs or as monetary value.
l Post sanction costs that fall outside of the typical EPC contract scope, such as theowner's project management cost, are not included by default. These costs can beoptionally added as a percentage of the project CAPEX costs or as monetary value.
l Contingencies within QUE$TOR are calibrated to target the P50 development cost.
l QUE$TOR is designed for use early in the project cycle. Therefore the estimatelevel that can be attained by using the program is typically within the range of +/-25% to 40%.
l The estimate produced is dependent on user entered values. Therefore, anyestimate should take into account the confidence of these values.
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Recommended System SpecificationsQUE$TOR is supported for the following operating systems:
l Windows XP service pack 2 or later
l Windows Vista
l Windows 7
l Windows 8.
The 32-bit (x86) and 64-bit (x64) versions of these operating systems are supported.
To run QUE$TOR in a terminal server environment requires the use of networklicences.
Minimum system specifications:
l 1 GHz Pentium 4 processor
l 512 MB RAM
l 250 MB disk space
l Minimum 1024x768 resolution
l CD ROM drive
Before installing QUE$TOR
l QUE$TOR requires that you install Windows Installer 3.1, Windows ImagingComponent and .NET framework 4 or later.
l QUE$TOR requires that the Sentinel SuperPro driver be installed on PCs that havea local security key (dongle) for their QUE$TOR licence.
l These are included on the CD.
Note: Administrator privileges are required to install these components.
Installation requirements
l QUE$TOR must be installed on a local PC. This must be done by a localadministrator. See the release notes for installation instructions.
l A licence must be available to run QUE$TOR; either a standalone dongle whichplugs directly into your computer or a network licence which is accessible acrossyour company network. Contact your IT department for further details.
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Exporting to Microsoft Excel from QUE$TOR
It is not necessary for Microsoft Excel to be installed on the PC that QUE$TOR isrunning on to perform an export to an Excel format file. However, to view theexported file requires Microsoft Excel 2003 SP3 or later. The exported files may openin earlier versions, however some of the formatting may be lost.
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Contacting Customer SupportAs part of the continuing licensing agreement for QUE$TOR, IHS offers a full technicalsupport service via its regional offices. Both computing and engineering supportrelating to the operation and understanding of the program are available.
The QUE$TOR support group has a dedicated support email address: [email protected]
Note: There is an 's', not a '$' in questor in the email address.
The IHS software support team key contacts are as follows:
North & CentralAmerica
Jonathan Stephens - Product Manager,[email protected] Verma - Senior Field Development Engineer,[email protected] Wahab - Cost Analyst, [email protected]
5333 WestheimerHoustonTexas 77056USA
Tel: (+1) 713 840 8282Fax: (+1)713 995 8593
South America Thais Hamilko - Product Specialist, E&I Prod Line-LATAM,[email protected]
Rua So Bento, 29 - 7o andarCentroRio de JaneiroRJ, CEP 20090-010Brazil
Tel: (+55) 21 3299 0440
Europe, Africa &Middle East
Rita Antonelli - Cost Manager, [email protected] Butcher - Field Development Engineer,[email protected] Helliwell - Engineering Advisor,[email protected] Williams - Engineering Manager,[email protected]
133 HoundsditchLondonEC3A 7BX
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UK
Tel: (+44) 20 3159 3300Fax: (+44) 20 3159 3299
S.E. Asia & Australia Sanjay Sinha - APAC Field Development SME,[email protected]
First Floor, Tower AVatika Business ParkSohan Road, Sec 49Gurgaon 122018 - HaryanaIndia
Tel: (+91) 124 454 2699
China Yaxing Wang - Sr. Customer Solution Advisor,[email protected]
Room 3001China World Office 1No.1, JianGuoMenWai AvenueBeijing100004China
Tel: (+86) 10 5633 4567Fax: (+86) 10 5633 4500
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CopyrightCopyright 2014, IHS Inc. and its affiliated and subsidiary companies, ALL RIGHTSRESERVED.
Windows and Excel are registered trademarks of Microsoft Corporation.
All other trademarks and service marks, including without limitation QUE$TOR,AS$ET and IHS ENERGY, belong to IHS Inc. and its affiliated and subsidiarycompanies, all rights reserved.
This product, including software, data and documentation, is licensed to theauthorised user for its internal business purposes only and no part thereof may bedisclosed, disseminated, sold, licensed, copied, reproduced, translated, transmittedor transferred to any third party. All rights reserved.
IHS Inc.15 Inverness Way EastEnglewood, Colorado 80112(303) 736-3000
Rev May 2014
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QUE$TOR StructureQUE$TOR is structured around a field development schematic (FDS) which allows youto create a visualisation of the development. The FDS is driven by a number of highlevel inputs which allow the development conditions to be specified.The basicprogram calculation sequence followed in QUE$TOR to generate a full life-cycle fieldor prospect development cost estimate is shown below.
To define the new project, QUE$TOR presents you with a series of forms that allowhigh level parameters of the development to be specified. Once you have reviewedand adjusted as necessary the default inputs in each form, click on OK to apply theinputs and move on to the next form.Click on Cancel to go back to the previous formand adjust any changes made.
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On starting each new project you will be led through the first four stages shownabove. Each of these stages will be populated with default values based upon yourchoices in the previous stage.
When the concept selector is completed, QUE$TOR will generate a complete costestimate immediately made up of a series of components, e.g. topsides, jacket,drilling and pipelines.
These components are all live linked to each other so that a change to one componentwill change all dependent components, e.g. jacket cost is dependent on topsidesoperating weight.You can enter and update these components and fix inputs so thatthey are no longer updated by the program.This is called locking. Although you canedit components in any order you should try to follow a logical path to avoid lockingvariables based on incorrect data.For example you should not lock the jacket weightuntil the topsides is fully defined. QUE$TORs order of calculation is explained infurther detail in Data flow and locking.
OPEX and Scheduling take data from all components to generate field operating costs(OPEX) and schedule the calculated capital and operating costs along with theproduction profile to give an overall project investment profile.
Once on the FDS
Cost estimates in QUE$TOR are made up of a number of individual components suchas topsides and jackets.Each of these components will influence or be dependent onthe design of associated components, e.g. jacket design is dependent on itsassociated topsides.Components are linked or docked to those components fromwhich they require data.There are also high level parameters defined withinQUE$TOR, such as reserves, which influence all components.
In generating a cost estimate QUE$TOR calculates one component at a time and thenpasses all requisite data on to the next component.The order of this is defined by thecalculation hierarchy.The concept selector generates a basic development plan froma selection of built-in defaults. The components selected by the concept are then runin the hierarchy order to provide a development capable of handling the wells andproduction defined in the production profile and field level data.
If you wish to fix parameters within a component, preventing them from beingrecalculated by the program, you can lock them.
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About Project PropertiesThe project properties is the starting point for defining a new project. It enables youto specify the location of the project, the procurement strategy and technicaldatabase to be used in the project and the preferred units.
Note: It is not possible to make changes in this screen once a project iscreated. However, the Project editor does allow the procurement strategy and thetechnical database to be changed once the project is saved.
l Name: enter a name for the project here.This will be the default file name whenyou save the project.
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Units of Measure
The units of measure define the units that will appear, both in the project and thereports. QUE$TOR has three built-in unit sets, metric, imperial and oilfield which areselected from the dropdown list.
Custom unit sets can be defined using the Unit editor.To select a user defined unitset, select the use custom unit set option button and use the Browse button to locateit. The default location for custom unit sets is: My Documents \IHS \QUE$TOR\Unit Sets.
Once in a project the units can be easily changed, for every input QUE$TOR providesa choice of relevant units. However the units in the reports are fixed by the choice ofunit set.
Main Product
The main product can be either oil or gas, the volume of the secondary product, e.g.associated gas when oil is selected, is defined by a ratio on the Field level data form.
This should typically be Oil if the gas oil ratio (GOR) is 400 bbl/MMscf (70 m3/million Sm3)].
Note: Once selected this cannot be changed in the project.
Selection will also affect the default field level data (but this can adjusted if required)which in turn will influence the field life and plateau production rate.
The default product type is set to the choice made in the last project you created, orto oil when QUE$TOR is shipped.
Location
QUE$TOR contains a database of typical field characteristics, extracted from the IHSIRIS21 E&P database. These are broken down on a basin by basin basis and providethe default properties for the field.Whilst you can overwrite all these characteristics,they can be useful if some data is unavailable.
Procurement strategy
This allows you to select the regional databases to be used for each of the costcentres for the new project. For example equipment could be sourced from NorthAmerica and design performed in Europe. The currency of the cost estimate can alsobe defined.
The box displays existing procurement strategies which can be chosen by selection.
To look for existing procurement strategies in a different folder, click on Browse.
Click on New to create a procurement strategy. When you create a new procurementstrategy QUE$TOR bases the default regional database on the location selected.SeeCreating procurement strategies for more information.
Click on View to examine a procurement strategy.
Click on Delete to delete the selected procurement strategy.
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Note: QUE$TOR does not ship with any built-in procurement strategies.
Technical database
The technical database contains regional specific technical data such asenvironmental data.QUE$TOR includes template databases for every offshore regionworldwide.The default database is based on the location chosen.To change to adifferent database, click on Browse.
You will be prompted to choose whether you want to use a template databasesupplied with QUE$TOR or use a custom database. See Technical Databases forfurther information.
Once you have adjusted all inputs as necessary, click OK. This applies your changesand closes the form to move on. Cancel will clear all entries in the form and takeyou back a step.
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Creating Procurement StrategiesProcurement strategies allow you to choose different regional cost databases foreach cost centre. They can also be used to choose the currency for the cost estimate.The cost data in each regional database is stored in either US dollars or the localcurrency (for the UK, Norway and the Netherlands). When cost databases are broughtinto the procurement strategy QUE$TOR converts them all into US dollars. You canedit the exchange rate used for this conversion. You can then choose a currency forthe cost estimate and enter the exchange rate from US dollars to this currency.
To create a new procurement strategy
1. Click Create new procurement strategy in the project properties form. Thisopens the form shown below.
2. Select a region and country.3. By default the cost database will be assigned a title which is the same as the
country selected; this can be overwritten.4. Click OK.5. The procurement strategy definition form is displayed.
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6. QUE$TOR has built in defaults for every country which it uses to choose wherecost centres are sourced from. To adjust the default region use the dropdownlists.
7. Check the exchange rate for each database. Some cost databases are in localcurrencies. In creating a procurement strategy QUE$TOR converts all costs to USdollars.A default exchange rate is entered if the cost database is in local currencybut this should obviously be treated with care and edited to reflect expectedexchange rates. The rate should be in the form of local currency to 1 US dollar,e.g. UK0.624 = US$1.