DOCSLIB.ORG

MODELING of UNCONTROLLED FLUID FLOW in WELLBORE and ITS PREVENTION a Dissertation by RUOCHEN LIU Submitted to the Office Of

Total Page：16

File Type：pdf, Size：1020Kb

Download full-text PDF Read full-text
MODELING of UNCONTROLLED FLUID FLOW in WELLBORE and ITS PREVENTION a Dissertation by RUOCHEN LIU Submitted to the Office Of MODELING OF UNCONTROLLED FLUID FLOW IN WELLBORE AND ITS PREVENTION A Dissertation by RUOCHEN LIU Submitted to the Office of Graduate and Professional Studies of Texas A&M University in partial fulfillment of the requirements for the degree of DOCTOR OF PHILOSOPHY Chair of Committee, M. Sam Mannan Co-Chair of Committee, A. Rashid Hasan Committee Members, M. Nazmul Krim Mahmoud El-Halwagi Head of Department, M. Nazmul Karim May 2016 Major Subject: Chemical Engineering Copyright 2016 Ruochen Liu ABSTRACT Uncontrolled fluid flow in the wellbore is one of the most critical safety concerns for the oil and gas industry. The major focus of this dissertation is on blowout events given the most severe consequences associated with such incidents. The past tragedies reflect a strong need for not only understanding the mechanisms of blowout to accurately estimate the consequence, but also the approaches to managing and controlling the risks, uncertainties, and hazards associated with blowout events. A fully integrated analytical model that couples the reservoir and wellbore has been proposed to investigate the fluid behaviors during the blowout events. This model could be used to simulate any potential blowout events for gas, oil, or oil/gas wells at onshore or offshore facilities. The reservoir, wellbore, and their interactions are coupled together to demonstrate a full picture of the potential well blowout incidents. The results reveal that understanding the importance of heat transfer and multi-phase flow behaviors is essential to accurately estimate the consequence of well blowouts. Well-established computational algorithms are developed to effectively estimate the blowout rate and total discharge amount during blowout incidents. The statistical analysis identifies the independent variables responsible for the maximum discharge; both reservoir permeability and the connected reservoir volume are the key variables. The results of the blowout modeling could serve as the input for both consequence-based and risk-based approaches to assess the risk associated with the blowout events. The application of such approaches is demonstrated by the case study. ii The consequence-based approach is easier to be implemented and provide guidance to the operators based on the realistic worst-case scenario. It would be useful for drilling site location selection and preparation of emergency response plan. On the other hand, the risk-based approach enables the operators to have a comprehensive understanding of the particular well that they are working on, so that the risk associated with the blowout events can be effectively managed and controlled. The risk reduction plan based on the blowout risk assessment is also discussed in this dissertation. iii DEDICATION To my wife, family and friends for all the endless support and grateful encouragement in facing all the challenges in completing this dissertation. iv ACKNOWLEDGEMENTS I would like to acknowledge and show my greatest appreciation to my advisor, Dr. M. Sam Mannan, for all his support and guidance throughout the course of this research. His professionalism and leadership has guided me to be ready for my next career, not only as an expert in the process safety field, but as a professional team player as well. I also would like to thank my co-advisor, Dr. A. Rashid Hasan, for his endless help on both technical and personal aspects during my Ph.D. program. My sincere thanks also goes to my committee members, Dr. Mahmoud El-Halwagi, and Dr. M. Nazmul Karim, for their continuous support and constructive suggestions. I am very grateful to Dr. Ray Mentzer for providing me with valuable guidance as a team leader. Special thanks to all the people working on offshore safety, Dr. Tony Rocha, Dr. Josh Richardson, Ms. Tatiana Flechas, and Mr. MD Nafiz E Tamim, for providing me with great support during the initial stage of my research. I want to thank Ms. Valerie Green, Ms. Alanna Scheinerman, Ms. Amarette Renieri, Ms. Towanna Arnold, and Ms. Ashley Stokes, for all their continuous support. I would like to express my sincere gratitude to all the friends and colleagues at the Mary Kay O’Connor Process Safety Center. Finally, thanks to my mother and father for their encouragement and to my wife for her patience and love. v TABLE OF CONTENTS Page ABSTRACT ....................................................................................................................... ii DEDICATION .................................................................................................................. iv ACKNOWLEDGEMENTS ............................................................................................... v TABLE OF CONTENTS .................................................................................................. vi LIST OF FIGURES ........................................................................................................... ix LIST OF TABLES ........................................................................................................... xii CHAPTER I INTRODUCTION AND LITERATURE REVIEW ................................... 1 1.1 Uncontrolled Fluid Flow ...................................................................................... 1 1.1.1 Incident History ............................................................................................. 1 1.1.2 Historical Statistics ........................................................................................ 6 1.1.3 Safety Barriers ............................................................................................. 13 1.2 Current Research and Practices to Address Blowout Events ............................. 16 1.2.1 Current Research ......................................................................................... 16 1.2.2 Consequence-based Assessment ................................................................. 17 1.2.3 Risk-based Assessment ............................................................................... 21 1.3 Statement of Problems and Significance ............................................................ 27 1.3.1 Research Motivation ................................................................................... 27 1.3.2 Research Objectives .................................................................................... 29 1.3.3 Research Methodology ................................................................................ 30 CHAPTER II CONSEQUENCE MODELING OF GAS WELL BLOWOUT .............. 32 2.1 Reservoir Model ................................................................................................. 33 2.2 Wellbore Model .................................................................................................. 34 2.2.1 Wellbore Dynamic Model for Single Phase Gas ........................................ 34 2.2.2 Heat Transfer ............................................................................................... 40 2.2.3 Sonic Velocity ............................................................................................. 49 2.3 Reservoir and Wellbore Interaction ................................................................... 51 2.3.1 Transient Period .......................................................................................... 52 2.3.2 Pseudo Steady-State Period ......................................................................... 53 2.3.3 Unified Model ............................................................................................. 55 vi 2.4 Computational Algorithm ................................................................................... 57 2.5 Results and Discussion ....................................................................................... 59 2.6 Conclusions ........................................................................................................ 70 CHAPTER III CONSEQUENCE MODELING OF OFFSHORE OIL WELL BLOWOUT ...................................................................................................................... 71 3.1 Reservoir Model ................................................................................................. 71 3.2 Wellbore Model .................................................................................................. 75 3.2.1 Multiphase Flow Model .............................................................................. 75 3.3 Reservoir and Wellbore Interaction ................................................................... 83 3.4 Computational Algorithm ................................................................................... 84 3.5 Results and Discussion ....................................................................................... 85 3.6 Conclusions ........................................................................................................ 93 CHAPTER IV PREVENTION AND MITIGATION OF BLOWOUT EVENTS ......... 95 4.1 Consequence-based Assessment of Blowout Events ......................................... 96 4.1.1 Plume Boundary .......................................................................................... 96 4.1.2 Explosions ................................................................................................. 101 4.1.3 Jet Fire ....................................................................................................... 103 4.1.4 Discussion ................................................................................................
Load more

Recommended publications
  • Production Management
    Process Solutions Guide Production Management Key Benefits Common Common GAS • Improve availability of wells and Header #1 Header #2 Gas Lift GAS facilities Production Separator OIL • Manage declining production and Well 1 Oil / Gas / Water WATER dynamic production characteristics Test Separator Flow • Improve reservoir modeling GAS Computer 3-Phase Separator OIL • Reduce cost of maintenance and Well 40 WATER operations 2-Phase GAS Turbine Water Cut Separator Meter Probe OIL & WATER Proven Coriolis Applications Net Oil Tank • Gas lift System Coriolis Computer Meter • Volume measure of oil, gas and MANUAL/AUTO produced water SAMPLING Process Diagram • Net oil / water cut Process Overview Production management involves establishing and maintaining optimal hydrocarbon production rates (oil / natural gas) while maximizing the overall recovery of the hydrocarbons available in the reservoir (yield). Production facilities are either oil or natural gas predominant and depending upon the type of reservoir or production methodology employed can produce various combinations and quantities of oil / condensate, natural gas and water. Well production is dependent upon the rate at which hydrocarbons flow toward the well bore and the reservoir pressure available to move the fluids to the surface for production. Over time, well production is typically assisted through artificial lift technology to help pump produced fluids to the surface. This can involve surface rod pumps, Electric Submersible Pumps, plunger lift or gas lift systems. Decline in reservoir pressure is countered with Secondary Recovery methods that involve the injection of natural gas or water back into the reservoir through injection wells to maintain reservoir pressure. The produced fluids from each well are measured to determine the volume production rate of oil, natural gas and water from each well in the field.
    [Show full text]
  • The Expanding Scope of Well Testing
    59605schD7R1.qxp:59605schD7R1 5/25/07 4:25 PM Page 44 The Expanding Scope of Well Testing Well testing has come a long way since the first drillstem test was run in 1926. From a simple composite packer and valve run on drillstring, the scope of well testing has blossomed into a broad array of sophisticated downhole and surface technologies. Hani Aghar Every E&P company wants to know what type of By measuring in-situ reservoir conditions and In Salah Gas (Joint venture of fluids its well will produce, what flow rates the fluids as they flow from the formation, the testing Sonatrach, BP and Statoil) well will deliver, and how long production can process gives E&P companies access to a variety Hassi-Messaoud, Algeria be sustained. Given the right planning, of dynamic and often unique measurements. technology and implementation, well testing can Depending on the scale of a test, some param - Mark Carie provide many answers to these important eters are measured at multiple points along the New Orleans, Louisiana, USA questions. In one form or another, well testing flow path, allowing engineers to compare Hani Elshahawi has been used to determine reservoir pressures, downhole pressures, temperatures and flow rates Shell International Exploration distance to boundaries, areal extent, fluid against surface measurements of the same and Production properties, permeability, flow rates, drawdown parameters (below). Through well testing, Houston, Texas, USA pressures, formation heterogeneities, vertical operators can extract reservoir fluid samples— layering, production capacity, formation damage, both downhole and at the surface—to observe Jaime Ricardo Gomez productivity index, completion efficiency changes in fluid properties and composition Jawaid Saeedi and more.
    [Show full text]
  • Well Testing Systems
    NORSOK STANDARD SYSTEM REQUIREMENTS WELL TESTING SYSTEMS D-SR-007 Rev.1, January 1996 Please note that whilst every effort has been made to ensure the accuracy of the NORSOK standards neither OLF nor TBL or any of their members will assume liability for any use thereof. Well testing systems D-SR-007 Rev. 1, January 1996 CONTENTS 1 FOREWORD 2 2 SCOPE 2 3 NORMATIVE REFERENCES 2 4 DEFINITIONS AND ABBREVIATIONS 3 4.1 Definitions 3 4.2 Abbreviations 3 5 FUNCTIONAL REQUIREMENTS 3 5.1 General 3 5.2 Products/services 3 5.3 Equipment/schematic 4 5.4 Performance/output 5 5.5 Regularity 5 5.6 Process/ambient conditions 5 5.7 Operational requirements 5 5.8 Maintenance requirements 7 5.9 Isolation and sectioning 7 5.10 Layout requirements 7 5.11 Interface requirements 7 5.12 Commissioning requirements 7 6 INFORMATIVE REFERENCES 8 ANNEX A SERVICE DATA SHEETS 9 ANNEX B EQUIPMENT DATA SHEET 19 NORSOK standard 1 of 38 Well testing systems D-SR-007 Rev. 1, January 1996 1 FOREWORD NORSOK (The competitive standing of the Norwegian offshore sector) is the industry initiative to add value, reduce cost and lead time and remove unnecessary activities in offshore field developments and operations. The NORSOK standards are developed by the Norwegian petroleum industry as a part of the NORSOK initiative and are jointly issued by OLF (The Norwegian Oil Industry Association) and TBL (The Federation of Norwegian Engineering Industries). NORSOK standards are administered by NTS (Norwegian Technology Standards Institution). The purpose of this industry standard is to replace the individual oil company specifications for use in existing and future petroleum industry developments, subject to the individual company's review and application.
    [Show full text]
  • Using Multi-Phase Flow Meters for Well Test Optimization in the New Digital Yet Cost Sensitive Environment
    Using Multi-Phase Flow Meters for Well Test Optimization in the new Digital yet Cost Sensitive Environment Daniel Sequeira Haimo America Inc. APR, 2020 Contents ❑ Conventional Well Testing ❑ Multiphase Meter Technology ❑ Why Multiphase Meters ❑ MPFM + AI in Well Testing ❑ Conclusions Conventional Well Testing Various types of well testing is conducted throughout the lifetime of producing wells • In the petroleum industry, a well test is the execution of a set of planned data acquisition activities. The acquired data is analyzed to broaden the knowledge and increase the understanding of the hydrocarbon properties therein and characteristics of the underground reservoir where the hydrocarbons are trapped….. The overall objective is identifying the reservoir's capacity to produce hydrocarbons, such as oil, natural gas and condensate. – Wikipedia • A “well test” is simply a period of time during which the production of the well is measured, either at the well head with portable well test equipment, or in a production facility – PetroWiki • Users of the well test data & information within the operator organization include amongst others Facilities, Production, Reservoir & Allocation Engineers, as also Hydrocarbon Accounting & senior management. Daily Well Testing - Allocation & Prod. Mgt Daily tests are conducted during production phase to obtain average daily production of oil, gas and water “Daily” test procedures usually require the rates of liquid, gas, pressure and temperature to be stable 24 hours or other fixed period. Due to "unstable" production conditions, and delays introduced by test separators, extended testing period is often required, sometimes reaching 5-7 days. Costs associated could be very high. Periodic well tests on the production plant is the conventional way to get an estimated or theoretical production contribution per phase fraction per well per month.
    [Show full text]
  • Well Integrity in Drilling and Well Operations
    NORSOK Standard D-010 Rev. 4, June 2013 Well integrity in drilling and well operations This NORSOK standard is developed with broad petroleum industry participation by interested parties in the Norwegian petroleum industry and is owned by the Norwegian petroleum industry represented by the Norwegian Oil and Gas Association and The Federation of Norwegian Industries. Please note that whilst every effort has been made to ensure the accuracy of this NORSOK standard, neither the Norwegian Oil and Gas Association nor The Federation of Norwegian Industries or any of their members will assume liability for any use thereof. Standards Norway is responsible for the administration and publication of this NORSOK standard. Standards Norway Telephone: + 47 67 83 86 00 Strandveien 18, P.O. Box 242 Fax: + 47 67 83 86 01 N-1326 Lysaker Email: [email protected] NORWAY Website: www.standard.no/petroleum Copyrights reserved Provided by Standard Online AS for Oljedirektoratet 2014-10-30 © NORSOK. Any enquiries regarding reproduction should be addressed to Standard Online AS. www.standard.no Provided by Standard Online AS for Oljedirektoratet 2014-10-30 D-010, Rev. 4, June 2013 NORSOK Standard D-010 Well integrity in drilling and well operations Contents 1 Scope ..................................................................................................................................................... 7 2 Normative and informative references ................................................................................................... 7 2.1
    [Show full text]
  • Guidance on Safety of Well Testing
    TECHNICAL REPORT MINERALS MANAGEMENT SERVICE (MMS) GUIDANCE ON SAFETY OF WELL TESTING REPORT NO. 4273776/DNV REVISION NO. 01 DET NORSKE VERITAS DET NORSKE VERITAS Report No:4273776/DNV rev. 01 TECHNICAL REPORT Date of first issue: Project No.: 2004-07-01 72501050 DET NORSKE V ERITAS Technology Services. N America Approved by: ~ Urqanisational unit: Ame Edvin L¢ken Marine & Process Systems 163.W Park Ten Place Head of Section Suite 100 Houston 7708-1 United Stairs c.;lient: Client ref.: Tel: + I 28 1 7'.! I 6600 Fa.: + I 18 1 7'.!I 6833 Minerals Management Service (MMS) Mathew Quinney hup //www dnv.com Summary: Based on a Joint Industry Project managed by DNV this report has been produced providing guidance on a number of key areas with respect to flow testing of wells. The guidance focuses on aspects of well testing which represent a departure from fairly traditional testing carried out in shallow water, and for which there is a relatively good safety record. The principal areas addressed include : • Testing from floating installations in deepwater • Testing of High Pressure High Temperature wells • Testing from Dynamically Positioned vessels • Temporary storage and offloading of crude oil • Testing in arctic areas The Guidance relates only to safety considerations and not operational efficiency. The Guidance is aimed at all the parties involved in a welJ test operation : - The Licensee (Operator) - Drilling Contractor - Service Company - Regulatory Inspector Reoort No.: Subject Group: 4273776/DNV Indexing terms RePort title: Kev words ervice Area Safety of Well Testing Safety Technical Well Testing Market ector Exploration D No distribution without permission from the client or responsible organisational unit D free distribution within DNV after 3 years D Strictly confidential Date of this revision: 15 Nov 2004 IZ! Unrestricted distribution Page i Rderence to part of this report which may kad to misinterpretation is nocpermissibk.
    [Show full text]
  • New Approach for In-Line Production Testing for Mature Oil Fields Using Clamp-On SONAR Flow Metering System
    New Approach For In-Line Production Testing for Mature Oil Fields Using Clamp-on SONAR Flow Metering System Giovanni Morra, Sara Scagliotti (Eni E&P) Dhia Naeem, Ali Al Alwan (South Oil Company Iraq) Siddesh Sridhar, Ahmed Hussein (Expro Meters) Abstract Monitoring produced oil, gas and water rates from individual wells plays an important role in reservoir management and production optimization. While beneficial, obtaining timely and accurate wellhead measurements can be challenging due to a range of factors. This paper describes a cost-effective and convenient approach to production surveillance of black oil wells using clamp-on flow meters (Sonar), integrated with a PVT and multiphase flow engine to calculate the properties of the produced fluids, and the individual phase flow rates. The PVT engine calculates the gas and liquid properties of the produced fluids, at the pressure and temperature conditions measured where the Sonar flow meter is clamped-on. The Sonar flow meter provides a direct measurement of the mixture flow velocity within the flow line. The mixture flow velocity is then interpreted in terms of actual gas and liquid flow rates. Once the gas and liquid flow rates are determined at actual conditions, the oil, water, and gas flow rates are reported at standard conditions based on the PVT data calculated by the PVT engine. The new approach was deployed in a mature field to test 6 different wells against existing conventional test separators as the reference. The tests showed that Sonar meters could be installed either upstream or downstream of the choke manifold thus allowing more flexibility in terms of field installation.
    [Show full text]
  • Occupational Safety and Health for Oil and Gas Well Drilling and Servicing Operations
    Occupational Safety and Health for Oil and Gas Well Drilling and Servicing Operations API RECOMMENDED PRACTICE 54 FOURTH EDITION, FEBRUARY 2019 Special Notes Neither API nor any of API’s employees, subcontractors, consultants, committees, or other assignees make any warranty or representation, either express or implied, with respect to the accuracy, completeness, or usefulness of the information contained herein, or assume any liability or responsibility for any use, or the results of such use, of any information or process disclosed in this publication. Neither API nor any of API’s employees, subcontractors, consultants, or other assignees represent that use of this publication would not infringe upon privately owned rights. Classified areas may vary depending on the location, conditions, equipment, and substances involved in any given situation. Users of this Recommended Practice should consult with the appropriate authorities having jurisdiction. API is not undertaking to meet the duties of employers, manufacturers, or suppliers to warn and properly train and equip their employees, and others exposed, concerning health and safety risks and precautions, nor undertaking their obligations to comply with authorities having jurisdiction. Information concerning safety and health risks and proper precautions with respect to particular materials and conditions should be obtained from the employer, the manufacturer or supplier of that material, or the material safety data sheet. Where applicable, authorities having jurisdiction should be consulted. Work sites and equipment operations may differ. Users are solely responsible for assessing their specific equipment and premises in determining the appropriateness of applying the Recommended Practice. At all times users should employ sound business, scientific, engineering, and judgment safety when using this Recommended Practice.
    [Show full text]
  • Petroleum Extension-The University of Texas at Austin I
    Petroleum Extension-The University of Texas at Austin i The Beam Lift Handbook First Edition, Revised by Paul M. Bommer and A. L. Podio Petroleum Extension-The University of Texas at Austin published by The University of Texas at Austin PETROLEUM EXTENSION 2015 iii Contents Figures x Tables xviii Foreword xxi Preface xxiii Acknowledgments xxv About the Authors xxvii Introduction xxix Reference xxxi 1. Beam Lift Goals and System Design 1-1 Goals 1-1 Unconstrained Design 1-4 Example 1, Initial Reservoir Pressure Just Above the Bubble Point 1-4 Example 2, Shallow Well Pumping From Reservoir Undergoing Successful Waterflood 1-18 Constrained Design 1-22 Example 3, Casing Size Limits Tubing Size 1-22 Example 4, Maximum Production Using Available Equipment 1-25 Example 5, Gear Box Capacity Constraint 1-28 Example 6, Flowing While Pumping 1-30 Example 7, Coal Bed Methane Pumping 1-32 Example 8, Pumping From Highly Deviated Wells 1-33 References 1-38 Bibliography 1-38 2. Monitoring and Analysis of Performance 2-1 Recommended Practices for the Monitoring and Analysis of Pumping System Performance 2-1 Dynamometer Analysis 2-1 Collecting Dynamometer Data 2-6 Data Quality Control 2-7 Analyzing the Dynamometer Data 2-8 Polished Rod Power 2-8 Valve Test 2-11 Fluid Load and Working Fluid Level 2-11 Wellbore Pressures 2-12 Maximum Gear Box Torque and Counterbalance Condition 2-13 Permissible Load Diagram 2-16 PetroleumFluid Slippage Extension-The and TV Leakage University of Texas at2-16 Austin The TV Test 2-17 Leakage Rate Calculation 2-20 TV Test for
    [Show full text]
  • Best Practices for Real Time Monitoring of Offshore Well Construction
    Best Practices for Real Time Monitoring of Offshore Well Construction DRAFT REPORT v3.0 03-MARCH, 2017 Prepared by: Eric van Oort, Nathan Zenero, and Cesar Gongora on Behalf of: Ocean Energy Safety Institute 1470 William D Fitch Pkwy, College Station, TX 77845 Best Practices for Real Time Monitoring of Offshore Well Construction Statement of Purpose In 2016, new well-control rules were established (CFR § 250.724) whereby operators are required to provide real-time monitoring plans and capabilities for operations in the OCS detailing at least the following technical and operational capabilities: • How the RTM data will be transmitted onshore, how the data will be labeled and monitored by qualified onshore personnel, and how the data will be stored onshore; • A description of procedures for providing BSEE access, upon request, to the RTM data including, if applicable, the location of any onshore data monitoring or data storage facilities; • Onshore monitoring personnel qualifications; • Methods and procedures for communications between rig and onshore personnel; • Actions that will be taken in case of loss of RTM capabilities or rig-to-shore communications; and • A protocol for responding to significant or prolonged interruptions of RTM capabilities or communications, including procedures for notifying the District Manager of such interruptions. As written the rule is open to interpretation. Therefore, to provide additional clarity regarding § 250.724 OESI has provide a collection of recommendations that are likely to satisfy the spirit of the rule without imposing undue burdens on operators or prescribing specific technologies or practices. The central purpose of this document is two-fold: 1.
    [Show full text]
  • Role of Well Testing and Information in the Petroleum Industry- Testing in Multilayers Reservoirs Assoc
    ISSN XXXX XXXX © 2016 IJESC Research Article Volume 6 Issue No. 7 Role of Well Testing and Information in the Petroleum Industry- Testing in Multilayers Reservoirs Assoc. Prof. Nevton KODHELAJ M.Sc. Shkëlqim BOZGO Abstract: The actual demand for oil and gas so as their products shows a clear increasing trend, despite some fluctuation mostly because of the global economic negative situation as well as some other geostrategic impacts. The new drilling activities and progressing toward deeper formations require stronger and abundant financial support, and looks that the safest way remains the increase of the oil recovery factor in the existing oil and gas fields. Well testing and their numerical modelling, gives responses that support their exploitation optimization. In many cases the oil and gas fields, represents as very complex systems composed by a large number of thin layers. Generally, they represent very complex hydrodynamic systems. The classification systems of these reservoirs, the calculation of the most important parameters, the factors that impacts and determine their exploitation performance as well as some economic indicators, are subject of this paper. Key words: Well test, reservoir, petroleum engineering, production forecats, skin effect 1 INTRODUCTION The oil well test represents one of the basic disciplines of the Oil & Gas Wells Testing reservoir engineering. The information collected regarding the fluid flow and the drawdown testing in the formation Pressure Data’s plays a key role for the determination of the productive Average Pressure of the Formation Use for Material Balance Calculations capacities of the oil and gas fields. The drawdown test gives Evaluation of the Vertical and Horizontal Evaluation of the Vertical and Horizontal Permeability an important support regarding the determination of the Anisotropy of the Permeability average pressure of the formations.
    [Show full text]