PIPESIM Fundamentals Fundamentals Workflow/Solutions Training Version 2010.1
Schlumberger Information Solutions November 3, 2010
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Table of Contents
About this Manual Learning Objectives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 What You Will Need . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 What to Expect . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 Course Conventions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 Icons . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 Workflow Diagram . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6
Module 1: PIPESIM Introduction Learning Objectives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9 Lesson 1: Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9 Lesson 2: A Tour of the User Interface . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 Lesson 3: PIPESIM File System and Calculation Engines . . . . . . . . . . . . . . . . 15 Output Files . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17 Lesson 4: Plots . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 Lesson 5: Single Branch Operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21 System Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21 Pressure/Temperature Profile . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22 Flow Correlation Comparison . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22 Data Matching . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22 NODAL Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23 Optimum Horizontal Well Length . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23 Reservoir Tables . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 Well Performance Curves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 Gas Lift Rate vs. Casing Head Pressure . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 Artificial Lift Performance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 Wax Deposition . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 Review Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25
Module 2: Simple Pipeline Tutorials Learning Objectives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27 Lesson 1: Single-Phase Flow Calculations . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27 Exercise 1: Modeling a Water Pipeline with Hand Calculations . . . . . . . . . . 29 Exercise 2: Modeling a Water Pipeline with PIPESIM . . . . . . . . . . . . . . . . . 32 Performing Operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38
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The Primary Output File . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 41 The Auxiliary Output File . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 43 Exercise 3: Analyzing Multiple Scenarios with Sensitivities . . . . . . . . . . . . . 45 Exercise 4: Modeling a Single-Phase Gas Pipeline . . . . . . . . . . . . . . . . . . . 49 Exercise 5: Calculating Gas Pipeline Flow Capacity . . . . . . . . . . . . . . . . . . 52 Lesson 2: Multiphase Flow Calculations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 54 Exercise 1: Modeling a Multiphase Pipeline . . . . . . . . . . . . . . . . . . . . . . . . . 57 Review Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 65 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 65
Module 3: Oil Well Performance Analysis Learning Objectives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 67 Lesson 1: NODAL Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 67 Getting Started . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 68 Exercise 1: Building the Well Model . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 69 Exercise 2: Performing NODAL Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . 73 Exercise 3: Performing a Pressure/Temperature Profile . . . . . . . . . . . . . . . 75 Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 76 Lesson 2: Fluid Calibration . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 76 Single Point Calibration . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 77 Multi-Point Calibration . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 77 Exercise 1: Calibrating PVT Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 78 GOR Property Definitions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 81 Lesson 3: Pressure/Temperature Matching . . . . . . . . . . . . . . . . . . . . . . . . . . . 82 Exercise 1: Flow Correlation Matching . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 83 Exercise 2: Matching Inflow Performance . . . . . . . . . . . . . . . . . . . . . . . . . . 86 Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 87 Lesson 4: Well Performance Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 87 Conducting a Water Cut Sensitivity Analysis . . . . . . . . . . . . . . . . . . . . . . . . 87 Exercise 1: Evaluating Gas Lift Performance . . . . . . . . . . . . . . . . . . . . . . . . 89 Exercise 2: Working with Multiple Completions . . . . . . . . . . . . . . . . . . . . . . 91 Question . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 95 Lesson 5: Flow Control Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 95 Exercise 1: Modeling a Flow Control Valve . . . . . . . . . . . . . . . . . . . . . . . . . 97 Review Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 98 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 98
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Module 4: Gas Well Performance Learning Objectives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101 Lesson 1: Compositional Fluid Modeling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101 Equations of State (EoS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 102 Binary Interaction Parameter (BIP) Set . . . . . . . . . . . . . . . . . . . . . . . . . . . 104 Exercise 1: Creating a Compositional Fluid Model for a Gas Well . . . . . . . 107 Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 110 Lesson 2: Gas Well Deliverability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 111 Exercise 1: Calculating Gas Well Deliverability . . . . . . . . . . . . . . . . . . . . . 112 Exercise 2: Calibrating the Inflow Model Using Multipoint Test Data . . . . . 115 Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 117 Lesson 3: Erosion Prediction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 117 API 14 E . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 117 Salama . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 118 Exercise 1: Selecting a Tubing Size . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 118 Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 120 Lesson 4: Choke Modeling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 121 Exercise 1: Modeling a Flowline and Choke . . . . . . . . . . . . . . . . . . . . . . . 122 Exercise 2: Predicting Future Production Rates . . . . . . . . . . . . . . . . . . . . 124 Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125 Lesson 5: Liquid Loading . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 126 Turner Droplet Model . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 126 Exercise 1: Determining a Critical Gas Rate to Prevent Well Loading . . . . 128 Review Question . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 129
Module 5: Horizontal Well Design Learning Objectives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 131 Lesson 1: Inflow Performance Relationships for Horizontal Completions . . . . 131 Exercise 1: Constructing the Well Model . . . . . . . . . . . . . . . . . . . . . . . . . . 134 Exercise 2: Evaluating the Optimal Horizontal Well Length . . . . . . . . . . . . 136 Exercise 3: Specifying Multiple Horizontal Perforated Intervals . . . . . . . . . 136 Review Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 137 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 137
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Module 6: Subsea Tieback Design Learning Objectives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 139 Lesson 1: Flow Assurance Considerations for Subsea Tieback Design . . . . . 140 Exercise 1: Developing a Compositional PVT Model . . . . . . . . . . . . . . . . 140 Exercise 2: Constructing the Model . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 142 Exercise 3: Sizing the Subsea Tieback . . . . . . . . . . . . . . . . . . . . . . . . . . . 144 Lesson 2: Hydrates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 145 Hydrate Mitigation Strategies in PIPESIM . . . . . . . . . . . . . . . . . . . . . . . . . 146 Exercise 1: Selecting Tieback Insulation Thickness . . . . . . . . . . . . . . . . . 147 Exercise 2: Determining the Methanol Requirement . . . . . . . . . . . . . . . . . 148 Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 150 Lesson 3: Severe Riser Slugging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 150 PI-SS Indicator (Severe-Slugging Group) . . . . . . . . . . . . . . . . . . . . . . . . . 152 Exercise 1: Screening for Severe Riser Slugging . . . . . . . . . . . . . . . . . . . 153 Lesson 4: Slug Catcher Sizing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154 Hydrodynamic Slugging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154 Pigging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 156 Ramp-up . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 158 Evaluating Each Scenario . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 158 Exercise 1: Sizing a Slug Catcher . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 159 Review Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 160 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 161
Module 7: Looped Gas Gathering Network Learning Objectives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 163 Lesson 1: Model a Gathering Network . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 163 Boundary Conditions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 164 Solution Criteria . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 164 Exercise 1: Building a Model of a Network . . . . . . . . . . . . . . . . . . . . . . . . . 165 Exercise 2: Performing a Network Simulation . . . . . . . . . . . . . . . . . . . . . . 173 Looped Gathering Network Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 175 Review Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 179 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 179
Module 8: Water Injection Network Learning Objectives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 181 Lesson 1: Crossflow in Multilayer Wells . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 181 Exercise 1: Determining Fluid Distribution in a Water Injection Network . . 182 Review Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 186 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 186
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Appendix A: PIPESIM 2010.1 Fundamentals Answer Key to Exercises Module 2: Simple Pipeline Tutorials . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 189 Lesson 1: Single-Phase Flow Calculations . . . . . . . . . . . . . . . . . . . . . . . . 189 Module 3: Oil Well Performance Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . 190 Lesson 1: Nodal Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 190 Lesson 2: Fluid Calibration . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 190 Lesson 3: Pressure/Temperature Matching . . . . . . . . . . . . . . . . . . . . . . . . 190 Lesson 4: Well Performance Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . 191 Question (Optional) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 191 Lesson 5: Flow Control Valve Modelling . . . . . . . . . . . . . . . . . . . . . . . . . . 191 Module 4: Gas Well Performance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 192 Lesson 2: Gas Well Deliverability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 192 Lesson 3: Erosion Prediction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 193 Lesson 4: Choke Modelling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 193 Lesson 5: Critical Gas Rate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 194 Module 5: Horizontal Well Design . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 194 Lesson 1: Inflow Performance Relationships . . . . . . . . . . . . . . . . . . . . . . . 194 Module 6: Subsea Tieback Design . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 194 Lesson 1: Flow Assurance Considerations for Subsea Tieback Design . . 194 Lesson 2: Hydrates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 194 Lesson 3: Severe Riser Slugging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 195 Lesson 4: Slug Catcher Sizing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 195 Module 7: Looped Gas Gathering Network . . . . . . . . . . . . . . . . . . . . . . . . . . 195 Lesson 1: Model a Gathering Network . . . . . . . . . . . . . . . . . . . . . . . . . . . . 195
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About this Manual
About this Manual This training provides an introduction into the PIPESIM software application. PIPESIM is a production engineer’s tool that covers a wide range of applications relevant to the oil and gas industry. Applications featured in this training manual include well performance, fluid modeling, flow assurance and network simulation.
Learning Objectives After completing this training, you will know how to: •
build a single branch well or pipeline model
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define a black oil or compositional fluid model
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perform single branch simulation operations
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build a network model
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perform a network simulation.
What You Will Need You must have the following hardware and software to complete the training: •
Personal computer with minimum 512 MB RAM
•
PIPESIM 2010.1
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Training data sets.
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What to Expect In each module within this training material, you will encount er the following: •
Overview of the module
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Prerequisites to the module (if necessary)
•
Learning objectives
•
A workflow component (if applicable)
•
Lessons, explaining a subject or an activity in the workflow
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Procedures, showing the steps needed to perform a task
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Exercises, which allow you to practice a task by using the steps in the procedure with a data set
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Scenario-based exercises
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Questions about the module
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Summary of the module. You will also encounter notes, tips and best practices.
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Course Conventions Characters typed in Bold
Represent references to dialog box names and application areas or commands to be performed. For example, "Open the Open Asset Model dialog." or “Choose Components.” Used to denote keyboard commands. For example, "Type a name and press Enter ." Identifies the name of Schlumberger software applications, such as ECLIPSE or Petrel.
Characters inside <> triangle brackets
Indicate variable values that the user must supply, such as
and .
Characters typed in italics
Represent file names or directories, such as "... edit the file sample.dat and..." Represent lists and option areas in a window, such as Attributes list or Experiments area. Identifies the first use of important terms or concepts. For example, "compositional simulation…" or “safe mode operation.”
Characters typed in fixed-width
Represent code, data, and other literal text the user sees or types. For example, enter 0.7323 .
NOTE: Some of the conventions used in this manual indicate the information to enter, but are not part of the information For example: Quotation marks and information between brackets indicate the information you should enter. Do not include the quotation marks or brackets when you type your information. Instructions to make menu selections are also written using bold text and an arrow indicating the selection sequence, as shown: 1. Click File menu > Save (the Save Asset Model File dialog box opens.) OR Click the Save Model
toolbar button.
An ‘OR’ is used to identify an alternate procedure.
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Icons Throughout this manual, you will find icons in the margin representing various kinds of information. These icons serve as at-a-glance reminders of their associated text. See below for descriptions of what each icon means.
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Workflow Diagram Figure 1 illustrates the workflow of the PIPESIM application.
Figure 1
PIPESIM workflow
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Summary In this introduction, we:
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defined the learning objectives
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outlined what tools you will need for this training
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discussed course conventions that you will encounter within this material
•
provided a high-level overview of the workflow.
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NOTES
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PIPESIM Introduction
Module 1 PIPESIM Introduction This module introduces PIPESIM 2010.1 and describes the graphical user interface (GUI) in detail to familiarize you with the application environment.
Learning Objectives After completing this module, you will know how to: •
create a new or open an existing project
•
navigate through the user interface
•
understand the structure of the output file
•
display plots in PsPlot.
You will also develop an understanding of PIPESIM toolbars, file system, engines, and operations.
Lesson 1
Introduction
PIPESIM is a steady-state, multiphase flow simulator used for the design and analysis of oil and gas production systems. With its rigorous simulation algorithms, PIPESIM helps you optimize your production and injection operations. As shown in Figure 2, PIPESIM models multiphase flow from the reservoir through to the surface facilities to enable comprehens ive production system analysis. PIPESIM is most often used by reservoir, production or facilities engineers as an engineering user type to model well performanc e, conduct nodal (systems) analysis, design artificial lift systems, model pipeline networks and facilities, and analyze field development plans and optimize production. NOTE: Steady-state flow simulation implies that the mass flow rate is conserved throughout the system. This means there is no accumulation of mass within any component in the system.
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Figure 2
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Total production system
PIPESIM modules are available and licensed separately, depending on your needs: Base System
Production system analysis software for well modeling, NODAL analysis, artificial lift design, pipeline/process facilities modeling and field development planning.
Network Analysis (NET)
Optional add-on to PIPESIM to model complex networks that can include loops, parallel lines and crossovers
Compositional Model
Optional add on to PIPESIM
Multiflash Package
Optional add-on to PIPESIM. Compositional model is not required.
Multiflash Hydrates
Optional add-on to Multiflash package.
Multiflash Wax Thermodynamics
Optional add-on to Multiflash package.
Multiflash Asphaltene Optional add-on to Multiflash package. PIPESIM Linux Used only with Avocet IAM when Computation Engines ECLIPSE Parallel and is run on a Linux Cluster
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Avocet Gas Lift Optimization Module
Network Optimization option that calculates the optimal gas lift allocation to a network of gas lifted wells
PIPESIM OLGAS Steady State Flow Correlation 2-Phase
Third-party 2-phase mechanistic multiphase flow model
PIPESIM OLGAS Steady State Flow Correlation 3-Phase
Third-party 3-phase mechanistic multiphase flow model
PIPESIM Rod Pump Design / Optimization
Third-party module for designing rod pumps
PIPESIM Rod Pump Diagnostics
Third-party module for diagnosing rod pump performance based on digitized dynocards
PIPESIM DBR Wax Deposition
Single-phase wax deposition model embedded in PIPESIM using wax properties characterized with the DBR Solids application
DBR Solids – Wax and Asphaltene Precipitation
Standalone application that predicts the wax and asphaltene precipitation temperature
DBR Solids – Wax Deposition Characterization
Standalone application that characterizes wax properties for use in PIPESIM wax deposition
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Lesson 2
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A Tour of the User Interface
The PIPESIM graphical user interface (GUI) allows you to easily construct well and network models within a single environment. To launch PIPESIM from the Start menu, select Program files > Schlumberger > PIPESIM. As shown in Figure 3, the PIPESIM interface consists of one main window, a menu bar, a status bar, a standard toolbar and three specific toolbars related to single branch and network modeling views.
Figure 3
PIPESIM toolbars and menus
The Standard toolbar (Figure 4) contains common commands that are displayed in both the single branch and network views. The Single Branch toolbar (Figure 5) is displayed only in single branch view, while the Network toolbar (Figure 6) and the Net Viewer toolbar are displayed in the Network view. You can hide the toolbars from view using the Menu bar.
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Menu Bar
PIPESIM Introduction
This has familiar Windows menus including File, File, Edit, Edit, Help, Help, and more. All the tools available in other toolbars, plus all operations in PIPESIM. PIPESIM.
Status Bar The status of running operation. If there is no operation running, it will show the path of model. Standard Toolbar
Figure 4
Single Branch Toolbar
Figure 5
Available in both single branch and network model and is comprised of the icons and processes shown in Fig Figure ure 4.
Standard to toolba lbar fu functio tionality ity
These tools (Fi (Fig gure ure 5) are available only in single branch models or the network model in single branch mode. It consists of all objects required to build the physical model. These tools can also be accessed from the Menu bar. Menu bar.
Single Br Branch to toolbar
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Network Toolbar
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This toolbar (Fi (Figu gure re 6) is available only in the network model view. It consists of all objects required to build the physical network model. These tools can also be accessed from the menu bar.
Figure 6
Network toolbar
NOTE: Icons in the Network toolbar Network toolbar and the Net Viewer bar bar are not highlighted in the Single Branch model. Similarly, Similarly, icons in the Single Branch toolbar Branch toolbar are not highlighted in the network model. From the Network model, you must access the Single Branch viewing mode by double-clicking on the object to insert necessary equipment, such as compressors, pumps, chokes, and more.
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Lesson 3
PIPESIM File System and Calculation Engines
PIPESIM generates PIPESIM generates several input and output files in its working directory when you run a model. The engines and file system are listed here: PIPESIM Engines
PIPESIM File System
•
PIPESIM uses PIPESIM uses one engine for a Single Branch model and another engine for a Network model.
•
Psimstub.exe is the PIPESIM engine PIPESIM engine for single branch operations
•
Pnetsub.exe is Pnetsub.exe is the PIPESIM engine PIPESIM engine for a network simulation
•
You can can set set or or cha chang nge e the the pat path h of thes these e engines by selecting Setup > Preferences > Choose Paths. Paths.
PIPESIM stores data in these formats: •
ASCII files
•
Binary files
•
Micr Micros osof oftt Acce Access ss dat databas abase. e.
The file extensions are processed by the simulation engine to create output files. Extension *.bps
Type of File Single branch model PIPESIM file PIPESIM file
Application Files All the data necessary to run a model. Single Branch model file includes data for units, fluid composition, well IPR, system data, and more. The support team requires these files when you make support queries.
*.bpn
Network model PIPESIM file PIPESIM file
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Same as above for a Network model.
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Extension *.out
Type of File Output file
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Output Files All output data in ASCII format. The output file is produced from both Single Branch and Network models. Node by node results are reported in output files. The output file is divided into sections. You have the option to show or hide a section by using Setup > Define Output. Output. Mostly, errors are reported in output file. Remember to check this file in case of an error in a PIPESIM model.
*.sum
Summary file
Summary report of PIPESIM output, PIPESIM output, such as pressures and temperatures at sources and sinks. Plot Files
*.plc
Profile plot
Variables you can plot with distance and elevation in PsPlot. PsPlot. These variables include pressure, temperature and fluid properties, and more. PsPlot is PsPlot is a plotting utility in PIPESIM. PIPESIM.
*.plt
System plot
Same as the *.plc file, file, but does not contain variables such as distance and elevation. This file is primarily used to see sensitivity of one variable to another. For example, you can plot water cut with system outlet pressure. Miscellaneous Files
*.psm
This is the keyword input file generated by the user interface for the PIPESIM single PIPESIM single branch engine named psimstub.exe named psimstub.exe.. In certain situations (mainly debugging), this file can be manually modified via expert mode.
*.tnt
All instructions sent to the PIPESIM network PIPESIM network engine - pnetstub.exe. pnetstub.exe. The PIPESIM engine PIPESIM engine reads this file for processing – not the *.bpn file. *.bpn file.
*.mdb
Access database file
Black oil fluid data, electric submersible pump (ESP) performance curves, user-defined pump and compressor curves, and pressure survey data. You can access this file by selecting Setup > Preferences > Choose Paths. Paths. You can set the path of this file in the Data Source box. Source box.
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Extension *.pvt
PIPESIM Introduction
Type of File PVT file
Miscellaneous Files A single stream composition and a table of fluid properties for a given set of pressure and temperature values. If needed, this file can be created by a commercial PVT package, such as Multiflash, Hysys, DBRSolids or others, or using the Compositional module in PIPESIM. PIPESIM.
*.unf
Unit file
Stores user-defined unit sets, which can be passed from user-to-user.
*.env
Phase envelope file
*.map
Flow regime map
Output Files The PIPESIM output PIPESIM output file is an ACSII format file, generated by either a Single Branch or a Network model. This is a very large file divided into many sections. You can customize the output report by selecting Setup > Define output ( output (Fi Figu gure re 7). Figu Figure re 8 is a sample of the output from the primary output section.
Figure 7
Define Output tab
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Figu Figure re 8
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Samp Sample le outp output ut file file (pri (prima mary ry outp output ut sect sectio ion) n)
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Lesson 4
Plots
Plots in PIPESIM are PIPESIM are displayed with a plotting utility called PsPlot. PsPlot. The path to the PsPlot executable PsPlot executable is normally located in the PIPESIM installation PIPESIM installation directory, such as C:\Program Files\Schlumb erger\PIPESIM\Programs\PSPlotX.exe.. erger\PIPESIM\Programs\PSPlotX.exe You can set the path of PsPlotX.exe by PsPlotX.exe by selecting Setup > Preferences > Choose Paths. Paths. You can use PsPlot to PsPlot to open both *.plc and and *.plt files. files. Optionally, you can view data in tabular mode (Fi (Figu gure re 9) by clicking on the Data tab. Data tab.
Figure 9
Tabular lar view of PsPlot lot data
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You can change display settings of PsPlot, such as title, minimum or maximum axis, color, legends and more, by selecting Edit > Advanced Plot Setup (Figure 10).
Figure 10
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Advanced Plot Setup dialog
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Lesson 5
Single Branch Operations
There are many single branch operations available in PIPESIM (Figure 11).
Figure 11
List of single branch operations
System Analysis The systems analysis operation enables you to determine the performance of a given system for varying operating conditions on a case-by-case basis. Results of the system analysis operation are provided in the form of plots of a dependent variable, such as outlet pressure, versus an independent variable, such as flow rate. You can generate families of X-Y curves for the system by varying either a single sensitivity variable (such as water cut) or by applying permutations of a group of sensitivity values. The ability to perform analysis by combining sensitivity variables in different ways makes the system analysis operation a very flexible tool for plotting data on a case-by-case basis.
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A typical plot resulting from a system analysis operation is shown in Figure 12.
Figure 12
Typical System Analysis plot
Pressure/Temperature Profile You can generate pressure and temperature profiles of the system as a function of distance/elevation along the system. Both temperature and pressure profiles are generated on a nodeby-node basis for the system. NOTE: The system analysis operation also generates Pressure/ Temperature profile plots for each case. Likewise, Pressure/Temperature Profile operations generate a system plot.
Flow Correlation Comparison Quickly compare various multiphase flow correlations against measured data. The Data Matching operation introduced in PIPESIM 2009.1 is recommended for regression of friction and holdup multipliers to tune multiphase flow correlations to match well test data.
Data Matching Select parameters that will be automatically adjusted to match measured pressure and temperature data for a particular system. These parameters include multipliers for heat transfer coefficient (to match temperature measurements), as well as friction factor and holdup factor multipliers (to match pressure measurements).
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This operation allows you to select and rank multiple flow correlations, and to simultaneously match pressure and temperature measurements.
NODAL Analysis A common way to analyze well performance is through a NODAL analysis plot to visually assess the impact of various system components. This is done by splitting the system at the point of interest known as the NODAL analysis point and graphically presenting the system response upstream (Inflow) and downstream (Outflow) of the nodal point. The point at which the inflow and outflow curves intersect is the operating point for the given system, as shown in Figure 13.
Figure 13
NODAL analysis Inflow/Outflow curves
Optimum Horizontal Well Length Predicts hydraulic well bore performance in the completion. The multiple source concept leads to a pressure gradient from the blind-end (toe) to the producing-end (heel) which, if neglected, results in over-predicting deliverability. The reduced drawdown at the toe results in the production leveling off as a function of well length, and it can be shown that drilling beyond an optimum length would yield no significant additional production.
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Reservoir Tables For the purposes of reservoir simulation, it is often necessary to generate VFP curves for input to a reservoir simulation program. The VFP curves allow the reservoir simulator to determine bottomhole flowing pressures as a function of tubing head pressure, flow rate, GOR, water cut and the artificial lift quantity. The reservoir simulator interface allows you to write tabular performance data to a file for input into a reservoir simulation model. Currently, the following reservoir simulators are supported: •
ECLIPSE
•
PORES
•
VIP
•
COMP4
•
MoReS (Shell’s in-house reservoir simulator).
Well Performance Curves These can be created in the network solver to produce faster solution times. A curve is created that represents the performance of the well under specified conditions. The network solver will then use this curve instead of modeling the well directly.
Gas Lift Rate vs. Casing Head Pressure Determines the gas lift injection rate possible based on the casing head pressure for a well.
Artificial Lift Performance Analyzes the effects of artificial lift of a production well using either gas lift or an electric submersible pump (ESP). The performance curves allow for sensitivities on various parameters, including wellhead pressure, water cut, tubing and flowline diameters.
Wax Deposition With various deposition model/methods, generates wax deposition profile (Distance vs. Wax deposition thickness) and system (Wax Volume against time) plots.
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Depending on selected methods, you must enter wax properties or provide a properties file. NOTE: The artificial lift operation is essentially a specific implementation of the system analysis operation.
Review Questions •
What is the basic premise of steady-state flow modeling?
•
What single branch operations are available?
Summary In the module, you gained an understanding of PIPESIM toolbars, file system and engines, and operations. You also learned about: •
starting PIPESIM with a new or existing project
•
navigating and learn the user interface
•
viewing results in output file
•
displaying plots in PsPlot
•
selecting single branch options
•
identifying PIPESIM executables and data files.
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NOTES
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Simple Pipeline Tutorials
Module 2 Simple Pipeline Tutorials The purpose of these tutorials is to familiarize you with the PIPESIM Single Branch interface by building and running simple examples. You begin by performing a simple hand calculation to determine the pressure drop in a water pipeline, and then construct a simple pipeline model to validate pressure drop along a horizontal pipeline for a given inlet pressure and flow rate. You will also run some sensitivity studies on the model.
Learning Objectives After completing this module, you will know how to: •
build the physical model
•
create a fluid model
•
choose flow correlations
•
perform operations
•
view and analyze results.
Lesson 1
Single-Phase Flow Calculations
Consider the case of a pipeline transporting water (Figure 14).
Figure 14
Pipeline transporting water
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The pressure change per distance L for single phase flow is given by Bernoulli’s equation:
dp dL
total
dp = dL
frictional
dp + dL
elevational
dp + dL
accelerational
The accelerational term is normally negligible except for low pressure and high velocity gas flow, although PIPESIM will always calculate this term. Assuming the accelerational term to be zero for your hand calculation, the pressure gradient equation becomes:
dp dL
f v 2 total
=
g sin (elevational) 2 gd (frictional) -
Where: = fluid density (lbm/ft3)
g = gravitational constant f = moody friction factor v = fluid velocity (ft/s) d = pipe inside diameter (ft)
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Exercise 1
Modeling a Water Pipeline with Hand Calculations
In this exercise, using the data in Table 1 and assuming the flow is isothermal, you perform a hand calculation to determine the delivery pressure of the pipeline using single-phase flow theory. NOTE: You will need a hand calculator or MS Excel to complete this exercise. Table 1: Water Pipeline Modelling Data Pipeline Data Diameter
d
3
in
Length
L
20,025
ft
Elevation Change
Z
1,000
ft
Horizontal Distance
X
20,000
ft
Ambient Temperature
Tamb
60
degF
Inclination Angle
q
2.866
º
Roughness
e
0.0015
in
Relative Roughness
/d
0.0005
in
(= 0.25 ft)
(=.05002 radians)
Fluid Data Water viscosity
w
1.2
cp
Water density
w
63.7
lbm/ft3
(= 8.06e-4 lb/ft-s)
Operating Data Source Temperature
Tinlet
60
degF
Inlet Pressure
Pin
1,200
psia
Water Flow rate
Qw
6,000
BPD
(= 0.39 ft3/s)
Constants Gravitational
g
32.2
ft/s2
TIP: To ensure unit consistency when performing hand calculations, refer to the converted unit in the far right column of the table.
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1. Calculate the water velocity:
Qw v d 2
4
= _____________ ft/s
2. Calculate the Reynold’s number:
Re
vd = ______________
Is the flow laminar or turbulent? (See the Moody diagram, Figure 15.) 3. Determine the friction factor using the Churchill equation for turbulent flow. NOTE: Alternatively, you can look up the friction factor using the Moody diagram in Figure 15.
f = __________________________
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Figure 15
Simple Pipeline Tutorials
Moody diagram
f v 2 4. Evaluate the frictional pressure term,
dp dL
friction
2 gd :
= __________ psf/ft
divide this by 144 to get_______ psi/ft 5. Multiply by the given length of pipe, L, to get the total frictional pressure drop:
dp friction = _____________ psi 6. Evaluate the elevational pressure term, sin NOTE: If using Excel, be sure the angle is in radians.
dp friction = __________ psf/ft divide this by 144 to get________ psi/ft
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7. Multiply by the given length of pipe, L, to get the total elevational pressure drop
dpelevation = _____________ psi 8. Add the frictional and elevational terms to determine the total pressure term:
9.
dp dL
total
dp = dL
dp dL
total
= ________ psi/ft
frictional
dp + dL
elevational
10. Multiply by the given length of pipe, L, to get the total pressure drop
dptotal = _____________ psi 11. Calculate the outlet pressure given the inlet pressure: P out = P in -
Exercise 2
dptotal = __________ psia
Modeling a Water Pipeline with PIPESIM
In this exercise, you use PIPESIM to build the water pipeline you hand calculated in . You will define parameters for each component in the model, perform operations, view and analyze the results, and compare PIPESIM results to your hand calculations. There are three parts to this exercise: 1. Starting the application 2. Creating the fluid model (water) and selecting flow correlations 3. Building the physical model.
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Getting Started To start the application: 1. Start PIPESIM by selecting Start > Program Files > Schlumberger > PIPESIM. 2. Click NEW Single Branch Model….
3. From the Setup > Units menu, select the Eng(ineering) units. 4. From the Setup > Define Output tab, uncheck all report options except Primary Output and Auxiliary Output .
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Building the Physical Model (a Water Pipeline Model) You begin by defining the physical components of the model. 1. Click Source and place it in the window by clicking inside the Single Branch window. 2. Click Boundary Node
3. Click Flowline
and place it in the window.
.
4. Link Source_1 to the End Node S1 by clicking and dragging from Source_1 to the End Node S1. NOTE: The red outlines on Source_1 and Flowline_1 indicate that essential input data is missing.
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5. Double-click Source_1 and the source input data user form displays. a. Fill in the form.
b. Click OK to exit the user form. 6. Double-click Flowline_1 and the input data user form is displayed. 7. Fill the form as shown below, ensuring that the rate of undulations = 0 (no terrain effects).
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8. Click the Heat Transfer tab and fill in the form for an adiabatic process, as no heat was gained or lost between the system and its environment.
9. Click OK to exit the user form and accept the overall heat transfer coefficient (U value) defaults.
Creating the Fluid Model (Water) and Selecting Flow Correlations To create the fluid model and select flow correlations: 1. Select Setup > Black Oil to open the Black Oil Fluid menu. 2.
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Fill in the Black Oil user form and click OK when you are finished.
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3. Select File > Save As and save the model as Exercise1_WaterPipe.bps . 4. From the Setup > Flow Correlations menu, select the Moody single-phase flow correlation.
5.
Click OK.
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Performing Operations PIPESIM Single Branch mode offers several simulation operations, depending on the intended workflow. Many of these operations are explained in the exercises that follow. The Pressure/Temperature Profile operation is used to acquire the distribution of pressure, temperature and many other parameters across the flow path. To perform these operations: 1. In the Operations menu, select the Pressure/Temperature Profile operation. NOTE: The Pressure Temperature Profile operation requires that you designate a calculated variable and specify all other variables. Generally, two specifications are provided for use with the rate, inlet pressure and outlet pressure, while the third is calculated. However, all three can be specified and a forth variable will be calculated, for example choke size. 2. Enter the known flowing conditions.
3. Click Run Model. The pressure calculation uses the Moody correlation (default single-phase correlation).
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4. View and analyze the results. The pressure profile bel ow should be visible upon completion of the run.
5. To display a tabular output of the Pressure/Temperature profile, click the Data tab at the top of your graph. Notice that the outlet pressure is 89 psia. 6. (Optional) Copy this data into Excel: a. Highlight the cells of interest. b. Press Ctrl + C. c. Select a cell in Excel and press Ctrl + V. d. To view an abbreviated form of the full output file, select Reports > Summary File. You can observe the output:
The Liquid holdup value displayed (175 bbl) is the total liquid volume for the entire pipe.
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7. The Summary file reports the frictional and elevational components of the total pressure change in the pipeline. Compare the results of PIPESIM to your hand calculations by entering the appropriate values in the table.
Result
Hand Calculation
PIPESIM
Liquid Velocity (ft/s)
∆Pfrictional (psi) ∆Pelevational (psi) ∆Ptotal (psi)
Outlet Pressure (psia)
8. View the output file by selecting Reports > Output File. By default, the output file is divided into five sections: • Input Data Echo (Input data and Input units summary) • Fluid Property Data (Input data of the fluid model) • Profile and Flow Correlations (Profile and selected correlations summary) • Primary Output • Auxiliary Output. NOTE: If the units reported in the output file are not the desired ones, you should change the units (Setup > Units), pick the preferred unit system, and rerun the simulation.
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The Primary Output File The primary output is shown in Figure 16.
Figure 16
Example of the primary output file
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The primary output contains 17 columns: •
Node number: node at which all the measures on the row have been recorded. (The nodes have been spaced by default with a 1,000 foot interval)
•
Horizontal Distance (cumulative horizontal component of length)
•
Elevation (absolute)
•
Angle of inclination (from the horizontal)
•
Angle of inclination (from the vertical)
•
Pressure
•
Temperature
•
Mean mixture velocity
•
Elevational pressure drop
•
Frictional pressure drop
•
Actual Liquid flow rate at the P,T conditions of the node
•
Actual Free gas rate at the standard P,T conditions of the node
•
Total Mass flow rate of the node
•
Actual Liquid density at the P,T conditions of the node
•
Actual Free gas density at the P,T conditions of the node
•
Slug Number
•
Flow Pattern.
Notice that, as the pressure decreases, the liquid density decreases, therefore the velocity must increase to maintain a constant mass flow rate.
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The Auxiliary Output File The auxiliary output is shown in Figure 17.
Figure 17
Example of the auxiliary output file
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The auxiliary output consists of 19 columns: •
Node number
•
Horizontal distance (cumulative)
•
Elevation (absolute)
•
Superficial liquid velocity
•
Superficial gas velocity
•
Liquid mass flow rate
•
Gas mass flow rate
•
Liquid viscosity
•
Gas viscosity
•
Reynolds number
•
No-slip Liquid Holdup Fraction
•
Slip Liquid Holdup Fraction
•
Liquid Water cut
•
Fluid Enthalpy
•
Erosional Velocity ratio
•
Erosion rate (if applicable)
•
Corrosion rate (if applicable)
•
Hydrate temperature sub-cooling (if applicable)
•
Liquid Loading Velocity Ratio (if Applicable).
TIP: The values of the Reynolds number indicate that the flow regime is turbulent (NRE > 2000) and are consistent with the results of the hand calculations.
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Exercise 3
Simple Pipeline Tutorials
Analyzing Multiple Scenarios with Sensitivities
In this exercise, you will continue using the previous example to explore how your model responds to different inlet temperatures. You will set a range of temperatures, perform operations, and view and analyze your results. To modify the P/T profile operation and view the output: 1. From the Operations menu, select the Pressure/Temperature Profile Operation. a. Select Source_1 as the Object and Temperature as the Variable. In the Pressure/Temperature Profile user form, click
.
b. Fill in the input form, as shown.
c. Click Apply and close the Set Range window. The completed form is shown in the figure.
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2. Click Run Model. The pressure calculation uses the Moody correlation (Default single phase correlation). 3. Observe the PsPlot output. This pressure profile should be visible upon completion of the run.
Notice that the highest inlet temperature generates the lowest pressure drop. As the temperature increases: • the viscosity decreases • the Reynolds number increases • the corresponding friction factor decreases • the frictional pressure gradient is lower. In other words,
Re T ↑ » ↓ »
vd ↑
dp » f ↓ » dL friction ↓
NOTE: In the case of water, the effect of the temperature on the density is negligible, as water is essentially an incompressible fluid.
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4. Select the Data tab in the Plot window to see all the data for each temperature in a tabular format. 5. Open the output file (*.out ). The output file can be opened in one of two ways: Click the Output File button from within the Operations (Pressure/Temperature Profiles) dialog:
OR Select Reports > Output File. By default, the output file contains the information for the first case only. (T = 20 degF). 6. To report all sensitivity cases: a. Select Setup > Define Output. b. Ensure that options are selected as shown in the figure. c. Set the number of cases to print to 4.
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7. Rerun the operation. TIP: If you do not change the operation or alter any of the parameters within the Operations menu, you can run the simulation by clicking Run
.
8. Open the output report to view the results of the four sensitivity cases. 9. To add segment data to your report, select Setup > Define Output and check the Segment Data in the Primary Output option. 10. Re-run the operation. 11. Open the output file and observe that additional segments have been inserted.
NOTE: By default, PIPESIM performs the pressure drop calculation for each of those additional segments to obtain precise averaged values of properties, such as liquid holdup or velocities at the main nodes.
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Exercise 4
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Modeling a Single-Phase Gas Pipeline
In this exercise, you investigate the flow of a single phase gas without changing the physical components of our previous example. To investigate the flow of a single phase gas: 1. Select Setup > Black Oil and modify the user form, as shown in the figure. This represents 100% gas a. Change Water Cut to WGR and GOR to OGR. b. Set values for WGR and OGR as 0. c. Rename the fluid as gas.
2. Under the Setup > Define Output menu, uncheck the box labeled Segment Data in Primary Output.
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3. Select Operations > Pressure/Temperature Profile and modify the Pressure/Temperature profile operation.
4. Click Run Model. As for the case of a single-phase liquid, the pressure calculation will be done using the Moody correlation. 5. Inspect the pressure profile plot upon completion of the run.
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In the previous example using water, the density remained constant because water is essentially incompressible. However, gas is a compressible fluid with a density described by the ideal gas law, rearranged into the following expression: g
pM zRT
Where: g = gas density
p = pressure M = Molecular Weight z = gas compressibility factor R = ideal gas constant T = Temperature Notice that the highest inlet temperatures yield the highest pressure drop. This is because, as the temperature increases the density decreases, which results in a decrease in the Reynolds number. Correspondingly, the friction factor increases and, as a result, the frictional pressure gradient is higher. In other words,
T ↑ » g ↓ »
Re
vd
↓
dp » f ↑ » dL
friction
↑
Also, because
dp dL
f v 2
= 2gd
friction
the velocity increase due to gas expansion has an exponential effect on the frictional pressure term. This accounts for the increase in the frictional gradient along the flowline and the curvature in the pressure profile plot. NOTE: The viscosity of the gas increases slightly with increasing temperature, but this effect is small and does little to offset the effects of decreasing density.
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Exercise 5
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Calculating Gas Pipeline Flow Capacity
In the previous exercises, you calculated the outlet pressure given a known inlet pressure and flow rate. In this exercise, you specify known inlet and outlet pressures and calculate the corresponding gas flow rate. There are three key variables involved in Single Branch operations: •
Inlet pressure
•
Outlet pressure
•
Flow rate.
Two of these variables must be specified but the third is calculated. Some operations allow you to specify all three variables, in which case a matching variable, such as pump speed or choke setting, must be specified. PIPESIM generally performs calculations in the direction of flow. Therefore, when the outlet pressure is calculated, as in the previous examples, the solution is non-iterative in that the outlet pressure is calculated during the first and only pressure traverse calculation. However, when outlet pressure is specified and either the inlet rate or the flow rate is calculated, the process becomes iterative, and successive estimates of the calculated variable are supplied until the calculated outlet pressure agrees with the specified pressure. To calculate gas deliverability: 1. Open the Pressure/Temperature Profiles user form and select Gas Rate as the calculated variable. 2. Specify 600 psia for the outlet pressure.
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3. Clear the temperature sensitivity values, shown in the figure, by highlighting the cells and pressing Ctrl + X.
4. Click Run Model on the user form. 5. Observe the PsPlot output. The gas flow rate corresponding to the specified pressure drop is shown in the legend beneath the profile plot.
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6. Observe the output files (*.out ). The iteration routine for this operation can be seen in the output file, as shown below. NOTE: To view this report, you must check Iteration Progress Log under Setup/Define Output)
7. Save your file as exer5.bps .
Lesson 2
Multiphase Flow Calculations
While pressure losses in single-phase flow in pipes have long been accurately modeled with familiar expressions such as the Bernoulli equation, accurate predictions of pressure loss in twophase flow have proved to be more challenging because of added complexities. The lower density and viscosity of the gas phase causes it to flow at a higher velocity relative to the liquid phase, a characteristic known as slippage. Consequently, the associated frictional pressure losses result from shear stresses encountered at the gas/liquid interface as well as along the pipe wall. Additionally, the highly compressible gas phase expands as the pressure decreases along the flow path. Further complicating matters are the variety of physical phase distributions that are characterized by flow regimes or flow patterns (Figure 18 and Figure 19). The prevailing flow pattern for a specific set of conditions depends on the relative magnitude of the forces acting on the fluids.
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Buoyancy, turbulence, inertia, and surface-tension forces are greatly affected by the relative flow rates, viscosities, and densities of a fluid, as well as the pipe diameter and inclination angle. The complex dynamics of the flow pattern govern slippage effects and, therefore, variations in liquid holdup and pressure gradient.
Figure 18
Multiphase flow regimes for horizontal flow
Figure 19
Multiphase flow regimes for vertical flow
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Many empirical correlations and mechanistic models have been proposed to predict liquid holdup and pressure loss. (Refer to the PIPESIM help system for details). Some are very general, while others apply only to a narrow range of conditions. Many of these approaches begin with a prediction of the flow pattern, with each flow pattern having an associated method of predicting liquid holdup. Because the gas travels faster in steady-state flow, it will occupy less pipe volume. The fraction of pipe volume occupied by the liquid is called the liquid holdup and is illustrated in Figure 20. Liquid holdup is generally the most important parameter in calculating pressure loss. Liquid holdup is also necessary to predict hydrate formation and wax deposition and to estimate the liquid volume expelled during pigging operations for sizing slug catchers. The liquid holdup prediction is used to determine a twophase friction factor from which a pressure gradient is calculated.
Figure 20
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Liquid Holdup
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Exercise 1
Simple Pipeline Tutorials
Modeling a Mu Multiphase Pipeline
The previous exercises explored single-phase flow of water and gas through a pipeline. In this exercise, you modify the existing pipeline model and explore multiphase flow. 1. Insert Report Tool flowline, as shown.
at the beginning and end of the
2. Click on on the flowline flowline to highligh highlightt the object and drag drag the the tip connected to the source to the first Report icon.
3. Release Release the the mouse mouse button button when when the the arrow arrow is on on top of of the Report Tool icon Tool icon and the flowline turns yellow.
4. Repeat Repeat the the previ previous ous step step for the second second Report Tool icon. Tool icon. 5. Select Connector the Source icon. Source icon.
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and connect the first Report Tool to Tool to
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6. Select th the Boundary node Boundary node and press the Delete key. Delete key. Your model should now displays as shown below:
7. Doubl Doublee-cli click ck on on each each of the Report Tool icons Tool icons and enter the data shown in the figure.
8. Doub Double le-c -cli lick ck on on the the Flowline and Flowline and select the Heat Transfer tab.
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9. Choose the typical typical Heat Transfer Transfer Coefficient Coefficient value for bare pipe exposed to air, air, as shown below.
10. Select Select Setup Setup > Black Oil and specify the fluid properties.
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11. From the Setup the Setup > Flow Correlations menu, Correlations menu, select Beggs and Brill Revised (Taitel-Dukler (Taitel-Dukler map) for the horizontal flow correlation and Hagedorn and Brown for the vertical flow correlation. NOTE: Observe that the Swap angle is set to 45º. This is the angle that corresponds to the switch between use of the vertical and horizontal flow correlation. In this example, the pipeline inclination angle is about 3º, which means that only the horizontal flow correlation correlat ion is used.
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12. Double-click on Source_1 and change the pressure to 4800 psia.
13. Select Operations > Pressure Temperature Profiles and enter the information. NOTE: The pressure drop is calculated using the Moody correlation (default single-phase correlation) and the Beggs and Brill Revised correlation. The results from the Taitel-Dukler Flow Regime map will be reported and will influence the pressure drop calculations performed by the Beggs and Brill Revised correlation if the flow regime is different from that predicted by the Beggs and Brill correlation.
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14. Run the model. 15. Observe the pressure profile plot.
16. From the Reports menu, open the output file. The following display can be seen in the primary output section of the output file.
Notice that the flow is initially single-phase liquid until the pressure falls below the bubblepoint upon which two-phase oil-gas flow is present. The single-phase Moody correlation is used in the first part of the pipe, and the Beggs and Brill multiphase correlation is used in the second part of the pipe after the pressure falls below the bubblepoint. TIP: The holdup for each of the segment can be seen in the auxiliary output.
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The number in the far right column is the Erosional Velocity Ratio (EVR = actual velocity/API 14e limit) and is displayed only when it is higher than 1. The spot reports output is shown in Figure 21. NOTE: To view the graphics and output in SI or Custom units, specify the units via the Setup > Units… option and rerun the model.
Figure 21
Sample spot report output
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The flow regime map (Figure 22) can also be viewed in PsPlot by selecting Reports > Flow Regime Map.
Figure 22
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Flow regime map
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Review Questions •
Which types of pressure drop contributions are reported by PIPESIM in output file (by default)?
•
What is the default single-phase flow correlation in PIPESIM?
•
How do you describe a Black Oil fluid model for water or dry gas?
•
Did you get any difference in pressure drop between hand calculation and PIPESIM reported results? If yes, why?
Summary In this module, you learned about: •
building the physical model
•
creating a fluid model
•
choosing flow correlations
•
performing operations
•
viewing and analyzing results.
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NOTES
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Oil Well Performance Analysis
Module 3 Oil Well Performance Analysis This module examines a producing oil well located in the North Sea. You analyze the performance of this well using NODAL analysis, calibrate black oil fluid (low GOR) using laboratory data, and match flow correlations with pressure survey data. You will also analyze the behavior of the well with increased water cut and find an opportunity to inject gas at a later stage when the well is unable to flow naturally.
Learning Objectives After completing this module, you will know how to: •
perform a NODAL analysis
•
estimate bottomhole flowing conditions
•
calibrate pressure, volume and temperature (PVT) data
•
perform flow correlation matching
•
perform inflow performance relationship (IPR) matching
•
conduct water cut sensitivity analysis
•
evaluate gas lift performance
•
install a flow control valve.
Lesson 1
NODAL Analysis
NODAL analysis evaluates the performance of an oil well. You specify a nodal point, usually at the bottomhole or wellhead, and divide the producing system into two parts: the inflow and the outflow. This is represented graphically in Figure 23. The solution node is defined as the location where the pressure differential upstream (inflow) and downstream (outflow) of the node is zero. Solution nodes can be judiciously selected to isolate the effect of certain variables.
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For example, if the node is taken at the bottomhole, factors that affect the inflow performance, such as skin factor, can be analyzed independently of variables that affect the outflow, such as tubing diameter or separator pressure.
Nodal Analysis Psep
PR
Pwf
Pwf
PR
Outflow
Psep 17
Figure 23
Intersection points of the inflow and outflow performance curves
Getting Started Before beginning an oil well performance analysis: 1. Select File > New > Well Performance Analysis. 2. From Setup > Units, set the engineering units.
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Exercise 1
Oil Well Performance Analysis
Building the Well Model
Model building refers to setting up all objects, from the source to the sink, and defining the properties of these objects. You can select PIPESIM single branch objects using either the Tool menu or the toolbar at the top of PIPESIM window. To build the well model: 1. Click Vertical Completion on the single branch toolbar to choose a vertical completion object and place it in the Single Branch flow diagram. 2. Click Boundary Node the flow diagram.
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and place the selected node in
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3. Click Tubing object and connect VertWell_1 to the End Node S1 by clicking and dragging from VertWell_1 completion to the End Node S1. NOTE: The red outlines on VertWell_1 and Tubing_1 indicate that essential input data are missing.
4. Double-click on the completion and enter the properties listed in the table. Reservoir and Inflow Data
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Completion model
Well PI
Use Vogel?
Yes
Reservoir Pressure
3,600 psia
Reservoir Temperature
200 degF
Liq. Productivity Index
8 stb/d/psi
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5. Double-click on the tubing object and enter the tubing properties based on data listed in the tables. Deviation Data Measured Depth (ft)
True Vertical Depth (ft)
0
0
1,000
1,000
2,500
2,450
5,000
4,850
7,500
7,200
9,000
8,550 Geothermal Gradient
Measured Depth (ft)
Ambient Temp. (degF)
0
50
9,000
200 Tubing Data
Bottom MD (ft)
Internal Diameter (inches)
8,600
3.958
9,000
6.184
6. Specify an Overall Heat Transfer Coefficient = 5 btu/hr/ft 2/F (override the default value). NOTE: Use the overall heat transfer coefficient to calculate total heat transfer through the pipe wall. The overall heat transfer coefficient depends on the fluids and their properties on both sides of the wall, as well as the properties of the wall and the transmission surface. 7. Click the Summary table button to observe the configuration summary. 8. Set the Distance between nodes to 100 ft. 9. Select Setup > Black Oil.
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10. Enter the fluid properties, as shown in the table. Assume default PVT correlations and no calibration data. Black Oil PVT Data Water Cut
10 %
GOR
500 scf/stb
Gas SG
0.8
Water SG
1.05
Oil API
36 ºAPI
The fluid physical properties are calculated over the range of pressures and temperatures encountered by the fluid and used by multiphase flow correlations to determine the phases present, the flow regime, and the pressure losses in single and multiphase flow regions. NOTE: The heat transfer calculations use the fluid thermal properties. 11. From the Setup > Flow Correlation menu, ensure that the Hagedorn-Brown correlation is selected for vertical flow and the Beggs-Brill Revised correlation is selected for horizontal flow. Select the correlation that is best suited for the fluid and operating conditions of interest. NOTE: There is no universal rule for selecting a multiphase flow correlation that is good for all operating scenarios. See the PIPESIM help system for information on the applicability of flow correlations. 12. Save the model as CaseStudy1_Oil_Well.bps .
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