This document provides an overview of oil and gas production processes. It begins with a brief history of oil drilling and uses. Section 2 provides a high-level process overview showing the key stages from wellheads through separation, compression, storage and export. The main stages include manifolds and gathering, separation, gas treatment and compression, and metering and export. Supporting utility systems are also outlined.
Oil dehydrators use electrostatic fields generated by electric grids to reduce the water content in crude oil. The dehydrator works similarly to electrostatic heater-treaters by causing water droplets in an emulsion to collide through rapid, random motion induced by the electric field. This causes the droplets to coalesce and separate, with water traveling to the bottom of the vessel to be drawn off while gas can be vented from the top. Dehydrators are able to more effectively reduce water content in crude oil to the typical goal of 0.5-1.0% volume when an electric field is applied.
This document provides information about valves technology and operations. It defines what a valve is, discusses common valve components like the body, bonnet, stem, disc and seat. It also covers different types of valves like globe valves, ball valves, gate valves, check valves and butterfly valves. The document classifies valves according to their function, application, motion and port size. It provides details on each valve type including their working principles, advantages and disadvantages.
This document provides information about Pakistan Refinery Limited (PRL), an oil refinery located in Karachi, Pakistan. It discusses PRL's background, facilities, and processes. Some key points:
- PRL was established in 1962 and is one of the major oil refineries in Karachi, with a capacity of 50,000 barrels per day.
- Its facilities include units for crude distillation, hydrotreating, reforming, water treatment, and steam/power generation.
- Like other refineries, PRL's main processes include distillation, treating, cracking, and conversion to produce fuels like gasoline and diesel from crude oil.
- It manages waste systematically by
Honda marine outboard bf225 a service repair manualfjjsekkfksmem
This document provides specifications and dimensional drawings for Honda BF200A/BF225A outboard motors in various configurations. It lists dimensions, weights, frame details, and types of models. The specifications section includes overall length, width, height, transom height, tilting angle/stage, trim angle, dry weight, and operating weight for each motor description code. The dimensional drawing section contains a single image showing measurements.
Phase separation occurs in a pressure vessel called a separator that is used to separate well fluids produced from oil and gas wells into gaseous and liquid components. Separators employ mechanisms like gravity settling, centrifugal force, and baffling to separate the phases. Separator design and performance is dependent on factors like flow rates, fluid properties, presence of impurities, and foaming tendencies. Common types of separators include test separators, production separators, and low temperature separators that are used for primary separation, secondary separation, and removal of specific phases like free water.
This document provides an overview of oil and gas separation and separator design. It discusses the purpose of separating oil, gas, and water streams and describes key principles of single-stage and multi-stage separation. It also outlines different types of separators, including horizontal and vertical separators. Horizontal separators use gravity to separate liquids from gases and include sections for inlet diversion, liquid collection, gas settling, and mist extraction. Vertical separators operate similarly with inlet diversion and counter-flow of liquids and gases.
TYPES OF PETROLEUM CONTRACTS AGREEMENT; Product Sharing Contract/Agreement (PSC/PSA); Concession (or Tax-and-Royalty) Contracts; STABILIZATION; EGYPTIAN HYDROCARBON FISCAL REGIME;; Main Differences Concessionary & Production Sharing Contracts (PSCs); Participation/Joint Venture/ Association (or Arrangements); Service Contracts; WHAT CHOICES OF LAW ARE POSSIBLE? Rule of Capture; Law of the Sea Act 77 & the Rule of Capture; KEY ISSUES IN UNITIZATION AGREEMENTS; UNITIZATION CLAUSES; Discretionary Unitization Clauses; Non-Discretionary Unitization Clauses; Cross-border or International Unitization; EGYPT PETROLEUM FUTURE; UNDERSTANDING EGYPT; PRODUCTION SHARING CONTRACTS AND TAX BARRELS; Egypt Production Sharing Contract (PSC); Typical Egypt Development Lease
This document provides assembly, component, and maintenance details for a floating head heat exchanger. It includes general assembly and cross-sectional views labeling major components like the shell, tube bundle, floating head, and distributor. Step-by-step maintenance procedures are described for activities like removing the bundle, hydrotesting the shell and tube sides, eliminating tube leaks, and final hydrotesting before unit startup. Safety and proper housekeeping during maintenance are emphasized.
Refineries process crude oil through distillation and other separation processes to produce fuels and other products. Crude oil is separated into components like gasoline, jet fuel, diesel, and residual fuel through units like atmospheric distillers, vacuum distillers, reformers, crackers, and hydrotreaters. Refineries also have utilities like hydrogen plants, sulfur recovery units, wastewater treatment, and power generation. Hazards in refineries include fires and explosions from flammable liquids and gases, exposure to toxic chemicals, and physical hazards from high pressures and temperatures.
PROJECT REPORT ON VARIOUS MECHANICAL UNITS INVOLVED IN THE BOTTLING OF LPG CY...Mohit Dhull
The document discusses an internship at an LPG bottling plant operated by Oil India Limited (OIL). It thanks the guides and training center for providing supervision and an opportunity to learn about the bottling of LPG cylinders. It also thanks managers and engineers for their direction and inputs during the study of mechanical units involved in LPG bottling operations.
Presentations about Oil & Gas separators, fundamentals and how they work in the industry developed by Hector Nguema having Petroskills course as a reference
Selection of Heat Exchanger Types
0 INTRODUCTION/PURPOSE
1 SCOPE
2 FIELD OF APPLICATION
3 DEFINITIONS
4 BACKGROUND
5 FACTORS INFLUENCING SELECTION
5.1 Type of Duty
5.2 Temperatures and Pressures
5.3 Materials of Construction 5.4 Fouling
5.5 Safety and Reliability
5.6 Repairs
5.7 Design Methods
5.8 Dimensions and Weight
5.9 Cost
5.10 GBHE Experience
6 TYPES OF EXCHANGER
6.1 Shell and Tube Exchangers
6.2 Cylindrical Graphite Block Heat Exchangers
6.3 Cubic Graphite Block Heat Exchangers
6.4 Air Cooled Heat Exchangers
6.5 Gasketed Plate and Frame
6.6 Spiral Plate
6.7 Tube in Duct
6.8 Plate-fin
6.9 Printed Circuit Heat Exchanger (PCHE)
6.10 Scraped Surface/Wiped Film Exchangers
6.11 Welded or Brazed Plate
6.12 Double Pipe
6.13 Electric Heaters
6.14 Fired Process Heaters
TABLE
(1) ADVANTAGES AND DISADVANTAGES OF DIFFERENT SHELL AND TUBE DESIGNS
FIGURES
1 ESTIMATED MAIN PLANT ITEM COSTS
2 ESTIMATED INSTALLED COSTS
3 TEMA HEAT EXCHANGER NOMENCLATURE
4 F ‘CORRECTION FACTORS' : TEMA E SHELL WITH EVEN NUMBER OF PASSE
5 SHELL AND TUBE HEAT EXCHANGER HEAD TYPES
6 GENERAL ARRANGEMENT OF A CYLINDRICAL GRAPHITE BLOCK HEAT EXCHANGER
7 EXPLODED VIEW OF A CUBIC GRAPHITE BLOCK
HEAT EXCHANGER
8 TYPICAL AIR COOLED HEAT EXCHANGER
9 GENERAL VIEW OF ONE END OF A 3-STREAM
PLATE-FIN HEAT EXCHANGER
10 TYPICAL PCHE PLATE
11 VICARB ‘COMPABLOC' EXCHANGER
12 ‘BROWN FINTUBE' MULTITUBE HEAT EXCHANGER
13 FIRED HEATER : SCHEMATICS AND NOMENCLATURE
Isuzu 4 hk1 diesel engine service repair manualfikdkksmmd
This document provides instructions for removing various engine components from an Isuzu 4HK1 diesel engine, including the cylinder head cover, turbocharger assembly, EGR cooler assembly, inlet pipe, fuel system components, cylinder head assembly, and injectors. The multi-page document includes detailed steps and diagrams for each removal procedure.
This document provides an overview of a course on petroleum gas processing. The course covers gas properties calculations, natural gas liquids extraction, liquid petroleum gas fractioning, and liquid natural gas production. It focuses on major unit process operations and some design aspects. The document reviews basic terminology and concepts, including elements, atoms, molecules, compounds, mixtures, and the periodic table. It also discusses the origin of gas and oil from organic materials buried underground, geological conditions for formation, and migration of crude oil.
This document provides information about side sliding doors (SSDs), including:
1) SSDs are also known as sliding sleeves that provide controlled communication between the tubing and casing annulus.
2) SSDs can be used for applications like fluid displacement, well killing, gas lifting, and chemical injection by opening or closing ports between the annulus and tubing.
3) SSD sleeves can be shifted using wireline methods, coiled tubing methods, pressure darts, or differential pressure application to the annulus.
The document discusses fire pump test meters from Pan Gulf Products. It describes two models - the Model-K and Model-M meters. The Model-K has a rating of 500 PSI but 275 PSI for 150# flanged units, comes with a 4-1/2" dial, and can be mounted on a venturi bracket or remotely with a hose. The Model-M has a rating of 175 PSI and comes with a 6" dial for mounting on a venturi bracket or remotely. Instructions are provided for installing and operating the meters to test fire pump performance.
ELECTRIC MOTOR (EM) DRIVEN COMPRESSOR IN ASPEN HYSYS DYNAMICSVijay Sarathy
Aspen HYSYS Dynamics provides the option of simulating centrifugal compressors with an Electric Motor (EM). In order to setup the electric motor, the following calculations can be made to arrive at the Electric Motor Input data in Aspen HYSYS Dynamics.
IRJET- Classification of Crude Oil and its CharacteristicsIRJET Journal
This document discusses the classification and characteristics of crude oil. It begins by defining crude oil as a natural mixture of hydrocarbons that may also contain compounds of sulfur, nitrogen, oxygen and metals. Crude oil is classified based on factors like density, chemical composition, and geographic origin. The composition of crude oil can vary significantly between different fields and production depths. Crude oil consists mainly of hydrocarbon compounds like paraffins, naphthenes and aromatics, along with small amounts of non-hydrocarbon compounds. Key characteristics of crude oil discussed include color, odor, water content, and density. Distillation characteristics and pour point are also evaluated to classify crude oils.
This document provides an overview of the oil refinery process. It discusses the three main stages of crude oil refining: separation, treating, and conversion. It describes the distillation unit and catalytic reforming unit processes. The conclusion summarizes that the document discussed crude oil and refineries, largest importers/exporters of crude oil, distillation, treatment units, and catalytic reforming.
Curso de Bombeio Mecânico - Rutácio CostaMeg Medeiros
O documento descreve os principais métodos de elevação de petróleo em poços, sendo o bombeio mecânico o mais utilizado no mundo. Explica o processo de perfuração e completação de poços, a necessidade de métodos de elevação artificial quando a pressão natural do reservatório não é suficiente, e os principais tipos de bombeamento mecânico, bombas de cavidades progressivas, bombeamento centrífugo submerso e gas lift.
Uiras João Magiua nasceu em 1992 em Notane, Moçambique. Ele viveu com sua avó até os 3 anos de idade, quando seu pai o levou de volta para casa. Entre 1997 e 2000, ele trabalhou como guardador de gado. Em 2001, iniciou sua educação formal, estudando até a 7a série em escolas locais. Atualmente, ele se sente um homem completo e tranquilo, apesar dos problemas do passado, com o apoio das pessoas ao seu redor.
O documento discute diferentes métodos de elevação de fluidos de poços de petróleo, incluindo elevação natural quando a pressão do reservatório é suficiente, e métodos artificiais como bombeio centrífugo submerso, bombeio por hastes mecânicas, gas-lift e bombeio por cavidades progressivas quando é necessária elevação induzida. Fatores como vazão, profundidade, viscosidade dos fluidos e custo operacional devem ser considerados na escolha do método.
O documento discute os principais mecanismos de produção em reservatórios de petróleo, incluindo mecanismo de gás em solução, mecanismo de capa de gás, mecanismo de influxo de água e mecanismo combinado. Também descreve métodos convencionais de recuperação, como injeção de água e gás, projetos de injeção e eficiência de recuperação.
Métodos de Elevação são utilizados para transportar determinado fluido de um ponto de maior pressão para o ponto de menor pressão. Estes subdividem-se em: natural e artificial.
Gurudev Goud has over 20 years of experience in digital sales and marketing across various industries and geographies. He has held leadership roles at companies such as SAP, Unizen Technologies, and MindTree. Goud has expertise in areas such as lead generation, social media marketing, paid advertising, user experience design, and data analytics. He has a track record of setting up global sales and marketing operations and launching new products and services.
This document provides an overview of oil and gas production processes and facilities. It was compiled by Håvard Devold from various sources to serve as an introduction for new engineers. The document describes the main sections of the production process including wellheads, manifolds, separation, compression, and storage. It also covers reservoir characteristics, exploration and drilling, artificial lift methods, and utility systems like control and safety systems. While not a complete technical reference, it aims to give readers an appreciation of the key aspects and design issues involved in upstream oil and gas production.
This DNV document outlines the technical standards, as developed by DNV, aimed at floating gas temrinals. Similar standards can be found in DNV.COM website, under "Resources".
The document summarizes the optimization of a TEG dehydration unit using recent advances in technology. Three technologies were selected to decrease the capital and operating costs and weight of the unit: liquid turbochargers, pervaporation membranes, and injection of semi-lean TEG. Simulation showed liquid turbochargers reduced energy consumption by 70%. Membranes decreased reboiling energy but were very costly. Semi-lean injection reduced equipment size but required design changes. The hybrid process doubled capital costs from the conventional design due to high membrane costs. Further research is needed to lower membrane prices and make them economically viable.
The document provides an overview of the Kjeldahl method for determining nitrogen content. It discusses the history of the method developed by Johan Kjeldahl in 1883. For over 130 years it has been an internationally accepted standard for determining nitrogen in various samples. The document outlines the typical procedures for Kjeldahl analysis including sample preparation, digestion, distillation, and titration. It also discusses parameters that affect the analysis and provides references for further information.
This document is a pocket manual from Solvay Fluor und Derivate GmbH about refrigeration and air conditioning technology. It provides an overview of Solvay as a company, the history of refrigerants, new generations of refrigerants including Solvay's refrigerants, basics of refrigeration calculations, general properties of refrigerants, and handling of refrigerants. The manual contains technical data, equations, and information to help with planning and designing refrigeration plants using Solvay refrigerants.
Ip model code of safe practice part 19 2nd ed. jan. 2007 part1Varadaraj Ck
The document notifies the customer that there is an editorial change needed to Model code of safe practice Part 19: Fire precautions at petroleum refineries and bulk storage installations (2nd edition). Specifically, section 4.8.3 paragraph 5 should include the word 'operational' so that it states the bund should be capable of holding 110% of the maximum operational capacity of the tank. Customers are asked to update their copy with this correction.
This document provides a manual for using the JOINTS add-on module for designing connections in steel and timber structures. It describes the module's features for inputting general data, defining nodes and members, applying loads and internal forces, and selecting national design annexes. It then gives guidance for using the module to analyze and design several common structural connection types, including steel column bases, tower joints, braced frames, and timber-to-steel connections. The document also reviews options for outputting results, evaluating designs, and printing reports and graphics.
This document discusses safety guidelines for bitumen and is from the Energy Institute. It is subject to a single-user license agreement. The document provides guidance on health management, fire prevention, firefighting, environmental protection, and other safety aspects of bitumen manufacture, storage, distribution, handling and use.
This report details the design of a process to treat 800 m3 per year of magnox nuclear waste and radioactive liquid effluent. The magnox dissolution process uses filtration, dissolution in acid, thermal decomposition, and calcination in a kiln to break down the solid waste into magnesium oxide. The liquid effluent treatment process uses ion exchange and carbonation to remove radioactive nuclides before storage. Material, energy, and radioactivity balances were performed to size the major equipment. Preliminary integration found the kiln off-gases could provide 47.3 kW of heat, reducing external heating needs while heat recovery between units lowers cooling requirements from 50.3 kW to 10.3 kW.
This document provides guidance on transformer maintenance for facilities. It discusses different transformer cooling methods, including dry type and liquid-immersed transformers. It outlines inspection procedures for various components of oil-filled transformers, such as the tank, bushings, oil preservation systems, and gaskets. The document also describes testing of transformer oils, including dissolved gas analysis to diagnose transformer condition. It provides guidance on moisture problems, annual oil tests, and electrical testing of transformers. The document contains extensive references and tables to aid in transformer maintenance and fault diagnosis.
162 pages Oil and gas production handbook(1).pdfkhadijabutt34
This document provides an overview of the oil and gas industry, including exploration, production, midstream, refining, and petrochemical processes and facilities. It begins with a brief history of oil exploration and uses, then describes the key upstream processes of well drilling, production, separation, and gas compression. Midstream facilities include gas plants, pipelines, and LNG liquefaction and regasification. Refining and petrochemical processes and products are also summarized. The document aims to provide engineers with an appreciation of the main characteristics and design issues across the industry.
This document provides a table of contents for a report on a urea production plant. The table of contents lists 9 chapters that will describe: 1) the introduction and history of the plant, 2) a literature review on urea production, 3) the production process description, 4) equipment specifications, 5) mass and energy balances, 6) utilities and waste handling, and 7) the laboratory. It also lists subsections that will be included in each chapter, such as discussions of raw materials, plant units, organization structure, health and safety, marketing, and analysis of process streams.
This document is a handbook about chlorine dioxide production systems from Grundfos. It discusses the chemical and physical properties of chlorine dioxide, different processes for generating chlorine dioxide on site, safety recommendations for storing reagents, how chlorine dioxide reacts with inorganic and organic compounds, and applications of chlorine dioxide such as drinking water disinfection, wastewater treatment, and food industry disinfection. The handbook provides detailed information about chlorine dioxide and its use in water treatment.
This document is the National Renewable Energy Laboratory's Biodiesel Handling and Use Guide, which provides information on producing, handling, and using biodiesel and biodiesel blends. It defines biodiesel as a non-petroleum, renewable fuel produced from domestic, sustainable resources such as plant oils or animal fats. The guide discusses biodiesel's benefits and properties, quality specifications, low-temperature properties, stability, and compatibility with engines and infrastructure. It also covers topics like the BQ-9000 quality program, engine warranties, taxes and incentives, safety considerations, and frequently asked questions about biodiesel.
New holland cr970 combine harvesters service repair manualfhsjejfksemm
This document is a repair manual for New Holland combines models CR920 through CR980. It provides repair instructions organized into sections covering the engine, transmission, hydraulics, electrical systems, threshing, cleaning, and other major systems. Safety precautions are outlined, noting hazards from chemicals, dust, electricity, and other factors. Proper service methods and repair procedures are emphasized to ensure safety and reliable machine operation.
New holland cr960 combine harvesters service repair manualfujsekfksmemer
This document is a repair manual for New Holland combines models CR920 through CR980. It provides repair instructions organized into sections covering the engine, transmission, hydraulics, electrical systems, harvesting components, and other areas of the combines. Safety precautions are outlined, and torque specifications and installation instructions are provided for hydraulic fittings and components.
New holland cr960 combine harvesters service repair manual instant downloadufjjsjekksekmm
This document is a repair manual for New Holland combines models CR920 through CR980. It provides repair instructions organized into sections covering the engine, transmission, hydraulics, electrical systems, harvesting components, and other areas of the combines. Safety precautions are outlined, and general information is provided on product identification, torque specifications, fittings, lubrication, and sealants to aid in repairs.
New holland cr920 combine harvesters service repair manual instant downloadufjjsjekksekmm
This document is a repair manual for New Holland combines models CR920 through CR980. It provides repair instructions organized into sections covering the engine, transmission, hydraulics, electrical systems, harvesting components, and other areas of the combines. Safety precautions are outlined, and general information is provided on product identification, torque specifications, fittings, lubrication, and sealants to aid in repairs.
New holland cr940 combine harvesters service repair manualfujsekksmem
This document is a repair manual for New Holland combines models CR920, CR940, CR960, CR970, and CR980. It contains sections on general information, safety precautions, the engine, transmission, hydraulics, electrical systems, threshing, cleaning, and other major systems. The manual provides instructions for troubleshooting, overhaul, and testing procedures to ensure repairs are completed safely and correctly. It notes that safety should be the top priority and any deviations from the procedures outlined must first ensure personal and machine safety are not compromised.
New holland cr940 combine harvesters service repair manual instant downloadufjjsjekksekmm
This document is a repair manual for New Holland combines models CR920 through CR980. It provides repair instructions organized into sections covering the engine, transmission, hydraulics, electrical systems, harvesting components, and other areas of the combines. Safety precautions are outlined, and general information is provided on product identification, torque specifications, fittings, lubrication, and sealants to aid in repairs.
Gurudev Goud is an experienced sales and marketing leader based in Bangalore, India. He has over 22 years of experience leading sales teams in North America, Europe, Asia Pacific, and India. Gurudev currently works as a startup mentor helping early-stage companies with business development, digital marketing, and global growth strategies.
LoRa is a low power wide area network technology that enables long range communication for internet of things devices. It uses a star-of-stars topology with end devices communicating with gateways using LoRa radio technology. Gateways are then connected to a central network server. LoRa supports bi-directional communication and uses frequency spreading to allow simultaneous communication on different data rates without interference. It provides encryption for secure communication and supports various device classes with different receive window capabilities. Unizen has expertise in developing solutions using LoRa technology.
This document describes several case studies across different domains including industrial automation, home automation, consumer electronics, defense, and SMAC. The case studies include mobile apps, IoT solutions, embedded systems, and web/cloud applications. Examples provided are a paint industry mobile app, an oil contamination monitoring system, generator monitoring and control, home security devices, music players, infotainment systems, and a real estate property booking system. The case studies showcase solutions leveraging technologies such as mobile, cloud, analytics, and embedded systems.
Unizen Technologies provides product engineering solutions and professional services in embedded domains like Internet of Things, lifestyle electronics, industrial automation, and defense/aerospace electronics. They work with customers from concept to production, offering services like product specification, rapid prototyping, software/hardware design, and production support. Their goal is to help customers commercialize ideas quickly with a proven track record of embedded solutions.
This document discusses four FPGA case studies:
1. A hardware accelerated high frequency trading platform with sub-microsecond latency for market data processing and order management.
2. A print controller for a handheld mobile printer using HP cartridges with sub-microsecond timing.
3. A transmit receive multi-module controller with a 200MT/s NAND flash interface.
4. A debug interface for a custom processor following the ARM Debug Interface V5 specification.
Unizen provides engineering services and solutions for defence, lifestyle and industrial segments. They have expertise in hardware, software, FPGA and application development. Some of their defence projects include developing a 3U VPX quad channel high-speed ADC board for data acquisition, porting a LynxOS 5.0 driver for a SATA controller, and porting U-Boot and VxWorks BSP for a QorIQ processor-based SBC. They also developed a VC++-based radar scan controller software and contributed to a beam steering controller system for an AEWACS program.
Unizen Technologies provides product engineering solutions and professional services in embedded domains like Internet of Things, lifestyle electronics, industrial automation, and defense/aerospace electronics. They work with customers from concept to production, offering services like product specification, prototyping, design, development, testing, and production support. Their goal is to help customers bring ideas to market quickly through quality engineering.
This document describes several case studies across different domains including industrial automation, home automation, consumer electronics, defense, and SMAC. The case studies include developing mobile apps, web services, IoT solutions, and more. Examples provided are a paint industry mobile app, an industrial automation HMI, generator monitoring system, home security device, music player, infotainment system, and a real estate property booking system. The document highlights technologies used such as Android, iOS, .NET, various sensors, cloud platforms, and more.
The document provides information about Hindustani classical music including its history and origins in North India. It discusses the Kirana gharana and its prominent artists such as Abdul Karim Khan, Sawai Gandharva, and Bhimsen Joshi. It also introduces the performers at the grand finale - Pandit Somanath Mardur, his son Kumar Mardur, and accompanist Shivanand Salimath, who are members of the Kirana gharana tradition.
Unizen provides Product Engineering Solutions and Professional Services in the Embedded domain. Unizen Technologies was founded by a team of high-caliber technology professionals with strong business acumen. The founders have a strong background in the embedded and enterprise security domains. They possess significant expertise in research, product engineering, technology consulting, pre-sales and support services. Their quality-driven engineering methodologies combined with a strong delivery focus make Unizen Technologies a preferred vendor for embedded and enterprise security solutions.
The founding team was instrumental in winning multi-million dollar deals during their stint with their previous organizations. They are well-recognized among the technical community. With a strong focus on customer satisfaction, they envision the goal of delivering quality solutions in a timely and cost-effective manner. They have good affiliations with technology companies in their domain, technology experts and with the alma mater.
The document describes OEM product offerings from Unizen Technologies for various industries including home automation, building automation, industrial automation, defense, aerospace, and homeland security. Some of the products mentioned include an IoT-enabled water purifier sensor, wall-mounted home assistant devices, industrial HMIs, wearable tracking modules, and various sensor modules. The document provides details on Unizen's capabilities and case studies for sample products they are developing.
The Smart Automation Design House provides home/building automation and security solutions through product engineering, professional services, and technology innovation programs. It has expertise in cutting-edge technologies and a strong delivery model that make it a preferred vendor for challenging engineering problems. It focuses on providing niche embedded solutions through software and hardware design, integration, and custom services to address customer needs.
This document outlines the top ten secrets of book writing according to Narendra Simone, who published 14 books after a career change from chemical engineering. Secret #2 is to develop a ready reference library of classic works to study techniques and build a digital collection of highlights and quotes for future inspiration, rather than relying on memory alone from reading. The recommendation is to use a Kindle to access many classics for free and build this reference library efficiently through digital annotation and organization. Having this resource will play a vital role in crafting novels.
This document discusses the issue of digital piracy from interviews with IT experts. The experts agree that piracy is on the rise due to easier sharing of information online and advances in technology like broadband internet. While companies spend millions fighting piracy, current solutions are limited and legal action is difficult across borders. The experts discuss how pricing digital content too high and restrictive digital rights management also contribute to piracy. They suggest that lowering prices through innovative licensing models and a combined effort of technological solutions, awareness campaigns, and policy changes could help address the issue over time.
The document discusses the challenges of measuring innovation. It notes that while innovation fuels R&D efforts, correctly gauging its market reception can translate to billions in revenue but an incorrect measure can spell doom for organizations. It examines issues like balancing innovation and market maturity, emphasizing value over creativity alone, and the incremental nature of innovation. The document also outlines IBM's emerging business opportunities framework for objectively measuring innovation processes.
Indian IT startups face intense competition from both domestic and overseas rivals. Domestically, startups compete with established Indian IT giants like Infosys and Wipro for large projects, but can find opportunities in niche areas ignored by the big players. Overseas, startups face competition from large international firms expanding into India as well as emerging players in countries like China, Romania, and Brazil. However, Indian startups have advantages in skills, a large talent pool, and an ability to provide high quality services at a lower cost. To succeed, startups must focus on these strengths while developing world-class solutions, services, and marketing to expand globally.
DESIGN GROUP, making a beginning way back in the year 1979 as a Consultancy Firm to cater to the Design Engineering needs of small civil Engineering and Electrical Engineering projects, has now growth into a full fledged Consultancy Organisation, providing its Design Engineering Consultancy services in various fields of Engineering related to very large projects.
Presently the DESIGN GROUP has been registered as a private limited company in the name and style of DESIGN GROUP Project Consultants Private Limited. ISO 9001-2000 Certificate has been conferred on the Organisation in the year 2004.
DESIGN GROUP has been providing various consultancy services required for the implementation of power projects from conceptual stage to completion and comissioning stage and operation and maintenance stage, Energy Audit and Modernisation Schemes for Electrical & Mechanical installations.
The firm has been retained by large industrial houses, firms and independent power producers in India, to extend planning and design engineering services for various projects.
The true strength of DESIGN GROUP is its dedicated and talented team members with more than 30 years of experience in the field of investigation, planning, design, implementation, management and operation and maintenance of large and small power plants and the engineering projects.
DESIGN GROUP is associated with various technical and professional institutions such as the Consulting Engineers Association of India, Central Power Research Institute, Bangalore, to keep abreast with the latest developments and practices in the various fields of engineering. It has entered into MOU with leading overseas consulting firms for providing specialised consultancy services and for taking up overseas projects.
DESIGN GROUP has been successfully providing pre-tender and post-tender services for various public sector undertakings such as Karnataka Power Transmission Corporation Ltd, Visweshwaraiah Vidyuth Nigam Ltd., and several private sector undertakings, for the bid preparation and analysis. These services include assessment of costs, detailed specifications of various items of work, conditions of contracts, tender documents, tender analysis and reports leading to selection of construction and supply agencies as per time bound schedules and needs of clients.
DESIGN GROUP has embarked upon extending its activities to overseas projects, especially in the Middle East Countries such as Saudi Arabia, Oman, United Arab Emirates and neighboring country Nepal.
With the backing of wealth of experience and dedicated service to its clients, DESIGN GROUP has become the most preferred Consultancy firm for extending Consultancy Services for Power Projects and other Engineering Projects.
This document is the table of contents for the 10th edition of the 2011-2012 IPLOCA Yearbook. It lists the contact information for IPLOCA and provides indexes of the regular onshore and offshore member companies, associate members, academic members, and advertisers in the yearbook. The table of contents provides an overview of the sections contained within the yearbook, including leadership reports, membership information, member profiles, photographs, and additional supporting information.
JBEIL Subsea Engineers Pvt. Ltd. is an engineering firm that specializes in subsea pipeline and SURF (Subsea Umbilicals Risers and Flowlines) design. They provide engineering services including route selection, hydraulic analysis, mechanical design, on-bottom stability analysis, spanning analysis, buckling analysis, and stress analysis. They have experience with major subsea pipeline projects in Australia, Russia, India, and other locations. Their team of engineers is led by Rajendra Kumar, who has over 20 years of experience in subsea pipeline design, and Yatish Yale, who focuses on installation engineering.
The Rise of AI in Cybersecurity How Machine Learning Will Shape Threat Detect...digitalxplive
Discover how artificial intelligence is revolutionizing cybersecurity in 2024. This presentation explores the impact of machine learning on threat detection, highlighting advancements, challenges, and future trends. Learn how AI-powered solutions enhance cyber defenses, mitigate risks, and adapt to evolving security landscapes.
leewayhertz.com-AI agents for healthcare Applications benefits and implementa...alexjohnson7307
In recent years, the integration of artificial intelligence (AI) in various sectors has revolutionized traditional practices, and healthcare is no exception. AI agents for healthcare have emerged as powerful tools, enhancing the efficiency, accuracy, and accessibility of medical services. This article explores the multifaceted role of AI agents in healthcare, shedding light on their applications, benefits, and the future they herald.
Data Integration Basics: Merging & Joining DataSafe Software
Are you tired of dealing with data trapped in silos? Join our upcoming webinar to learn how to efficiently merge and join disparate datasets, transforming your data integration capabilities. This webinar is designed to empower you with the knowledge and skills needed to efficiently integrate data from various sources, allowing you to draw more value from your data.
With FME, merging and joining different types of data—whether it’s spreadsheets, databases, or spatial data—becomes a straightforward process. Our expert presenters will guide you through the essential techniques and best practices.
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4. CONTENTS
1 Introduction............................................................................................. 1
2 Process overview ................................................................................... 3
2.1 Facilities ......................................................................................... 4
2.1.1 Onshore ................................................................................ 5
2.1.2 Offshore ................................................................................ 6
2.2 Main process sections ................................................................... 9
2.2.1 Wellheads ........................................................................... 10
2.2.2 Manifolds/gathering ............................................................ 10
2.2.3 Separation........................................................................... 11
2.2.4 Gas compression ................................................................ 12
2.2.5 Metering, storage and export .............................................. 13
2.3 Utility systems .............................................................................. 14
3 Reservoir and wellheads ...................................................................... 15
3.1 Crude oil and natural gas ............................................................ 15
3.1.1 Crude oil.............................................................................. 15
3.1.2 Natural gas.......................................................................... 17
3.1.3 Condensates ....................................................................... 18
3.2 The reservoir ............................................................................... 18
3.3 Exploration and drilling ................................................................ 20
3.4 The well ....................................................................................... 23
3.4.1 Well casing.......................................................................... 23
3.4.2 Completion .......................................................................... 25
3.5 Wellhead ...................................................................................... 26
3.5.1 Subsea wells ....................................................................... 28
3.5.2 Injection............................................................................... 29
3.6 Artificial lift ................................................................................... 29
3.6.1 Rod pumps.......................................................................... 30
3.6.2 Downhole pumps ................................................................ 30
3.6.3 Gas lift ................................................................................. 31
3.6.4 Plunger lift ........................................................................... 32
3.7 Well workover, intervention and stimulation. ............................... 33
4 The oil and gas process ....................................................................... 35
4.1 Manifolds and gathering .............................................................. 37
4.1.1 Pipelines and risers ............................................................ 37
4.1.2 Production, test and injection manifolds ............................. 37
4.2 Separation ................................................................................... 38
4.2.1 Test separators and well test .............................................. 38
4.2.2 Production separators ......................................................... 38
4.2.3 Second stage separator ...................................................... 40
4.2.4 Third stage separator .......................................................... 40
4.2.5 Coalescer ............................................................................ 41
ii
5. 4.2.6 Electrostatic desalter .......................................................... 41
4.2.7 Water treatment .................................................................. 41
4.3 Gas treatment and compression ................................................. 43
4.3.1 Heat exchangers ................................................................. 43
4.3.2 Scrubbers and reboilers...................................................... 44
4.3.3 Compressor anti surge and performance ........................... 45
4.3.4 Gas treatment ..................................................................... 50
4.4 Oil and gas storage, metering and export ................................... 50
4.4.1 Fiscal metering.................................................................... 50
4.4.2 Storage ............................................................................... 53
4.4.3 Marine loading .................................................................... 54
4.4.4 Pipeline terminal ................................................................. 54
5 Gas processing and LNG ..................................................................... 55
5.1 Gas processing............................................................................ 57
5.1.1 Acid gas removal ................................................................ 58
5.1.2 Dehydration......................................................................... 59
5.1.3 Mercury removal ................................................................. 59
5.1.4 Nitrogen rejection ................................................................ 60
5.1.5 NGL recovery and treatment .............................................. 60
5.1.6 Sales gas specifications ..................................................... 60
5.2 LNG ............................................................................................. 62
5.2.1 LNG liquefaction ................................................................. 62
5.2.2 Storage, transport and regasification .................................. 65
6 Utility systems ...................................................................................... 66
6.1 Process Control Systems ............................................................ 66
6.2 Safety systems and Functional Safety ........................................ 69
6.2.1 Emergency Shutdown and Process Shutdown .................. 71
6.2.2 Fire and Gas System .......................................................... 73
6.3 Telemetry/SCADA ....................................................................... 75
6.4 Integrated Operations .................................................................. 76
6.4.1 Reservoir management and drilling operations .................. 77
6.4.2 Production optimization ...................................................... 77
6.4.3 Asset Optimization and maintenance Support ................... 78
6.4.4 Information Management Systems (IMS) ........................... 80
6.4.5 Training simulators ............................................................. 81
6.5 Power generation, distribution and drives ................................... 82
6.6 Flare and atmospheric ventilation ............................................... 84
6.7 Instrument air............................................................................... 85
6.8 HVAC ........................................................................................... 85
6.9 Water systems ............................................................................. 85
6.9.1 Potable water ...................................................................... 85
6.9.2 Seawater ............................................................................. 86
6.9.3 Ballast water ....................................................................... 86
iii
6. 6.10 Chemicals and additives.............................................................. 87
6.11 Telecom ....................................................................................... 89
7 Unconventional and conventional resources and environmental effects
92
7.1 Unconventional sources of oil and gas........................................ 92
7.1.1 Extra heavy crude ............................................................... 93
7.1.2 Tar sands ............................................................................ 93
7.1.3 Oil shale .............................................................................. 94
7.1.4 Shale gas and coal bed methane ....................................... 95
7.1.5 Coal, gas to liquids and synthetic fuel ................................ 96
7.1.6 Methane hydrates ............................................................... 97
7.1.7 Biofuels ............................................................................... 98
7.1.8 Hydrogen .......................................................................... 100
7.2 Emissions and environmental effects ........................................ 100
7.2.1 Indigenous emissions ....................................................... 101
7.2.2 Greenhouse emissions ..................................................... 101
7.2.3 Carbon capture and sequestration ................................... 104
8 Units ................................................................................................... 107
9 Acronyms ........................................................................................... 109
10 References ......................................................................................... 111
11 Index................................................................................................... 112
iv
7. 1 Introduction
Oil has been used for lighting purposes for many thousands of years. In
areas where oil is found in shallow reservoirs, seeps of crude oil or gas may
naturally develop, and some oil could simply be collected from seepage or
tar ponds.
Historically, we know of the tales of eternal fires where oil and gas seeps
would ignite and burn. One example from is the site where the famous oracle
of Delphi was built around 1000 B.C. Written sources from 500 B.C. describe
how the Chinese used natural gas to boil water.
But it was not until 1859 that "Colonel" Edwin Drake drilled the first
successful oil well, with the sole purpose of finding oil. The Drake Well was
located in the middle of quiet farm country in north-western Pennsylvania,
and began the international search for an industrial use of petroleum.
Photo: Drake Well Museum Collection, Titusville, PA
These wells were shallow by modern standards, often less than 50 meters
deep, but produced large quantities of oil. In the picture from the Tarr Farm,
1
8. Oil Creek Valley, The Phillips well on the right initially produced 4000 barrels
a day in October 1861 and the Woodford well on the left came in at 1500
barrels a day in July, 1862.
The oil was collected in the wooden tank pictured, in the foreground. As you
will no doubt notice, there are many different sized barrels in the background
of the picture. At this time, barrel size had not been standardized, which
made terms like "Oil is selling at $5 per barrel" very confusing (today a barrel
is 159 liters, see units at the back). But even in those days, overproduction
was something to be avoided. When the "Empire well" was completed in
September 1861, it gave 3,000 barrels per day, flooding the market, and the
price of oil plummeted to 10 cents a barrel.
Soon, oil had replaced most other fuels for motorized transport. The
automobile industry developed at the end of the 19th century, and quickly
adopted oil as fuel. Gasoline engines were essential for designing successful
aircraft. Ships driven by oil could move up to twice as fast as their coal
powered counterparts, a vital military advantage. Gas was burned off or left
in the ground.
Despite attempts at gas transportation as far back as 1821, it was not until
after the World War II that welding techniques, pipe rolling, and metallurgical
advances allowed for the construction of reliable long distance pipelines,
resulting in a natural gas industry boom. At the same time the petrochemical
industry with its new plastic materials quickly increased production. Even
now gas production is gaining market share as LNG provides an economical
way of transporting the gas from even the remotest sites.
With oil prices of 70 dollars a barrel or more, even more difficult to access
sources have become economically viable. Such sources include tar sands
in Venezuela and Canada as well as oil shales and coal bed methane,.
Synthetic diesel (syndiesel) from natural gas and biological sources
(biodiesel, ethanol) have seen a dramatic increase over the last 10 years.
These sources may eventually more than triple the potential reserves of
hydrocarbon fuels.
2
9. 2 Process overview
The following illustration gives a simplified overview of the typical oil and gas
production process
Production Metering and
Production Gas compressors Export
and Test storage
Wellheads
Manifolds
LP HP
Gas
Meter Pig Gas
Launcher Pipeline
Pig Oil
Launcher Pipeline
Production Separators
1 stage
Tanker
Loading
2 stage
Crude Oil
ø pump Meter
Water treatment
Test Separator
Oil Storage
Drilling Utility systems (selected)
Power Generation
Injection Injection
wells manifold
Water injection Instrument Air
pump Mud and Cementing
Potable Water
Gas injection
compressor
Firefighting
systems
HVAC
Figure 1. Oil and gas production overview
3
10. Today oil and gas is produced in almost every part of the world, from the
small 100 barrels a day private wells, to the large bore 4000 barrel a day
wells; in shallow 20 meter deep reservoirs to 3000 meter deep wells in more
than 2000 meters of water; in 10,000 dollar onshore wells to 10 billion dollar
offshore developments. Despite this range many parts of the process are
quite similar in principle.
At the left side, we find the wellheads. They feed into production and test
manifolds. In a distributed production system this would be called the
gathering system. The remainder of the diagram is the actual process, often
called the Gas Oil Separation Plant (GOSP). While there are oil or gas only
installations, more often the well-stream will consist of a full range of
hydrocarbons from gas (methane, butane, propane etc.), condensates
(medium density hydrocarbons) to crude oil. With this well flow we will also
get a variety of unwanted components such as water, carbon dioxide, salts,
sulfur and sand. The purpose of the GOSP is to process the well flow into
clean marketable products: oil, natural gas or condensates. Also included
are a number of utility systems, not part of the actual process, but providing
energy, water, air or some other utility to the plant.
2.1 Facilities
Figure 2. Oil and gas production facilities
4
11. 2.1.1 Onshore
Onshore production is economically
viable from a few dozen barrels of oil
a day and upwards. Oil and gas is
produced from several million wells
world-wide. In particular, a gas
gathering network can become very
large, with production from thousands
of wells, several hundred
kilometers/miles apart, feeding
through a gathering network into a
processing plant. The picture shows a
well equipped with a sucker rod pump
(donkey pump) often associated with
onshore oil production. However, as
we shall see later, there are many
other ways of extracting oil from a non-free flowing well
For the smallest reservoirs, oil is simply collected in a holding tank and
picked up at regular intervals by tanker truck or railcar.
But onshore wells in oil rich areas are also high capacity wells with
thousands of barrels per day, connected to a 1,000,000 barrel or more a day
gas oil separation plant (GOSP). Product is sent from the plant by pipeline or
tankers. The production may come from many different license owners,
therefore metering and logging of individual well-streams into the gathering
network are important tasks.
Recently, very heavy crude,
tar sands and oil shale have
become economically
extractable with higher prices
and new technology. Heavy
crude may need heating and
diluents to be extracted. Tar
sands have lost their volatile
compounds and are strip
mined or can be extracted
with steam. It must be further
processed to separate
bitumen from the sand.
5
12. These unconventional reserves may contain more than double the
hydrocarbons found in conventional reservoirs. The picture shows the
Syncrude Mildred plant at Athabasca, Canada Photo: GDFL Jamitzky/Wikimedia
2.1.2 Offshore
A whole range of different structures are used offshore, depending on size
and water depth. In the last few years we have seen pure sea bottom
installations with multiphase piping to shore and no offshore topside
structure at all. Replacing outlying wellhead towers, deviation drilling is used
to reach different parts of the reservoir from a few wellhead cluster locations.
Some of the common offshore structures are:
A shallow water complex,
which is characterized by a
several independent platforms
with different parts of the
process and utilities linked with
gangway bridges. Individual
platforms include Wellhead
Platform, Riser Platform,
Processing Platform,
Accommodations Platform and
Power Generation Platform.
The picture shows the BP
Valhall complex. Typically found in water
depths up to 100 meters.
A gravity base. This consists of
enormous concrete fixed structures placed
on the bottom, typically with oil storage
cells in the "skirt" that rests on the sea
bottom. The large deck receives all parts
of the process and utilities in large
modules. Large fields at 100 to 500 meters
water depth were typical of the 1980s and
90s. The concrete was poured at an on-
shore location, with enough air in the
storage cells to keep the structure floating
until tow-out and lowering onto the
seabed. The picture shows the world's
largest GBS platform, Troll A, during
construction. Photo StatoilHydro
6
13. Compliant towers are much like fixed platforms. They consist of a narrow
tower, attached to a foundation on the seafloor and extending up to the
platform. This tower is flexible, as opposed to the relatively rigid legs of a
fixed platform. This flexibility allows them to operate in much deeper water,
as they can 'absorb' much of the pressure exerted by the wind and sea.
Compliant towers are used between 500 and 1000 meters water depth.
Floating production, where all
topside systems are located on
a floating structure with dry or
subsea wells. Some floaters are:
FPSO: Floating Production,
Storage and Offloading. Their
main advantage is that they are
a standalone structure that does
not need external infrastructure
such as pipelines or storage.
Crude oil is offloaded to a
shuttle tanker at regular
intervals, from days to weeks,
depending on production and
storage capacity. FPSOs today
produce from around 10,000 to
200,000 barrels per day.
An FPSO is typically a tanker
type hull or barge, often
converted from an existing crude
oil tanker (VLCC or ULCC). Due
to the increasing sea depth for
new fields, they dominate new
offshore field development at
more than 100 meters water depth.
The wellheads or subsea risers from the sea bottom are located on a central
or bow-mounted turret so that the ship can rotate freely to point into wind,
waves or current. The turret has wire rope and chain connections to several
anchors (position mooring - POSMOOR), or it can be dynamically positioned
using thrusters (dynamic positioning – DYNPOS). Most installations use
subsea wells. The main process is placed on the deck, while the hull is used
for storage and offloading to a shuttle tanker. May also be used for the
transportation of pipelines.
7
14. FPSOs with additional processing and systems such as drilling and
production and stranded gas LNG production are planned.
A variation of the FPSO is the
Sevan Marine design. This uses a
circular hull which shows the same
profile to wind, waves and current
regardless of direction. It shares
many of the characteristics of the
ship-shaped FPSO such as high
storage capacity and deck load,
but does not rotate and therefore
does not need a rotating turret.
Photo: Sevan Marine
A Tension Leg Platform (TLP –
left side in picture) consists of a
structure held in place by vertical
tendons connected to the sea floor
by pile-secured templates. The
structure is held in a fixed position
by tensioned tendons, which
provide for use of the TLP in a broad water depth range up to about 2000m.
Limited vertical motion. The
tendons are constructed as hollow
high tensile strength steel pipes
that carry the spare buoyancy of
the structure and ensure limited
vertical motion.
Semi-submersible platforms
(front of picture) have a similar
design but without taut mooring.
This permits more lateral and
vertical motion and is generally
used with flexible risers and
subsea wells.
Something similar are Seastar
platforms which are miniature
floating tension leg platforms,
much like the semi-submersible
type, with tensioned tendons.
8
15. A SPAR consists of a single tall
floating cylindrical hull, supporting a
fixed deck. The cylinder does not
however extend all the way to the
seabed, but is tethered to the bottom
by a series of cables and lines. The
large cylinder serves to stabilize the
platform in the water, and allows for
movement to absorb the force of
potential hurricanes. SPARs can be
quite large and are used for water
depths from 300 and up to 3000
meters. SPAR is not an acronym,
but refers to its likeness to a ship's
spar. SPARs can support dry completion wells, but are more often used with
subsea wells.
Subsea production systems are wells located on the sea floor, as opposed
to on the surface. As in a floating production system, the petroleum is
extracted at the
seabed, and can
then be 'tied-back'
to an already
existing production
platform or even an
onshore facility,
limited by horizontal
distance or "offset".
The well is drilled
by a moveable rig and the extracted oil and natural gas is transported by
undersea pipeline and riser to a processing facility. This allows one
strategically placed production platform to service many wells over a
reasonably large area. Subsea systems are typically in use at depths of 500
meters or more, and do not have the ability to drill, only to extract and
transport. Drilling and completion is performed from a surface rig. Horizontal
offsets of up to 250 kilometers/150 miles are currently possible. Photo:
StatoilHydro
2.2 Main process sections
We will go through each section in detail in the following chapters. The
summary below is an introductory synopsis of each section
9
16. 2.2.1 Wellheads
The wellhead sits on top of the actual oil or gas well leading down to the
reservoir. A wellhead may also be an injection well, used to inject water or
gas back into the reservoir to maintain pressure and levels to maximize
production.
Once a natural gas or
oil well is drilled, and it
has been verified that
commercially viable
quantities of natural gas
are present for
extraction, the well must
be 'completed' to allow
for the flow of petroleum
or natural gas out of the
formation and up to the
surface. This process
includes strengthening
the well hole with
casing, evaluating the
pressure and temperature of the formation, and then installing the proper
equipment to ensure an efficient flow of natural gas from the well. The well
flow is controlled with a choke.
We differentiate between, dry completion (which is either onshore or on the
deck of an offshore structure) and subsea completions below the surface.
The wellhead structure, which is often called a Christmas tree, must allow for
a number of operations relating to production and well workover. Well
workover refers to various technologies for maintaining the well and
improving its production capacity.
2.2.2 Manifolds/gathering
Onshore, the individual well streams are brought into the main production
facilities over a network of gathering pipelines and manifold systems. The
purpose of these pipelines is to allow set up of production "well sets" so that
for a given production level, the best reservoir utilization, well flow
composition (gas, oil, water) etc. can be selected from the available wells.
For gas gathering systems, it is common to meter the individual gathering
lines into the manifold as shown on the illustration. For multiphase
10
17. (combination of gas, oil and water) flows, the high cost of multiphase flow
meters often leads to the use of software flow rate estimators that use well
test data to calculate the actual flow.
Offshore, the dry
completion wells on the
main field centre feed
directly into production
manifolds, while
outlying wellhead
towers and subsea
installations feed via
multiphase pipelines
back to the production
risers. Risers are the
system that allows a
pipeline to "rise" up to
the topside structure.
For floating or
structures, this involves
a way to take up weight and movement. For heavy crude and in Arctic areas,
diluents and heating may be needed to reduce viscosity and allow flow.
2.2.3 Separation
Some wells have pure gas
production which can be taken
directly to gas treatment
and/or compression. More
often, the well gives a
combination of gas, oil and
water and various
contaminants which must be
separated and processed. The
production separators come in
many forms and designs, with
the classical variant being the
gravity separator. Photo: JL Bryan Oilfield Equipment
In gravity separation, the well flow is fed into a horizontal vessel. The
retention period is typically 5 minutes, allowing the gas to bubble out, water
to settle at the bottom and oil to be taken out in the middle. The pressure is
often reduced in several stages (high pressure separator, low pressure
11
18. separator etc.) to allow controlled separation of volatile components. A
sudden pressure reduction might allow flash vaporization leading to
instability and safety hazards.
2.2.4 Gas compression
Gas from a pure natural gas wellhead might have sufficient pressure to feed
directly into a pipeline transport system. Gas from separators has generally
lost so much pressure that it must be recompressed to be transported.
Turbine driven compressors gain their energy by using a small proportion of
the natural gas that they compress. The turbine itself serves to operate a
centrifugal compressor, which contains a type of fan that compresses and
pumps the natural gas through the pipeline. Some compressor stations are
operated by using an electric motor to turn the same type of centrifugal
compressor. This type of compression does not require the use of any of the
natural gas from the
pipe; however it
does require a
reliable source of
electricity nearby.
The compression
includes a large
section of
associated
equipment such as
scrubbers (to
remove liquid
droplets) and heat
exchangers, lube oil
treatment etc.
Whatever the source of the natural gas, once separated from crude oil (if
present) it commonly exists in mixtures with other hydrocarbons, principally
ethane, propane, butane, and pentanes. In addition, raw natural gas
contains water vapor, hydrogen sulfide (H2S), carbon dioxide, helium,
nitrogen, and other compounds.
Natural gas processing consists of separating all of the various
hydrocarbons and fluids from the pure natural gas, to produce what is known
as 'pipeline quality' dry natural gas. Major transportation pipelines usually
impose restrictions on the make-up of the natural gas that is allowed into the
pipeline. That means that before the natural gas can be transported it must
be purified.
12
19. Associated hydrocarbons, known as 'natural gas liquids' (NGL) are used as
raw materials for oil refineries or petrochemical plants, and as sources of
energy.
2.2.5 Metering, storage and export
Most plants do not
allow local gas storage,
but oil is often stored
before loading on a
vessel, such as a
shuttle tanker taking oil
to a larger tanker
terminal, or direct to a
crude carrier. Offshore
production facilities
without a direct
pipeline connection
generally rely on crude
storage in the base or
hull, to allow a shuttle tanker to offload about once a week. A larger
production complex generally has an associated tank farm terminal allowing
the storage of different
grades of crude to take
up changes in demand,
delays in transport etc.
Metering stations allow
operators to monitor
and manage the
natural gas and oil
exported from the
production installation.
These employ
specialized meters to
measure the natural
gas or oil as it flows through the pipeline, without impeding its movement.
This metered volume represents a transfer of ownership from a producer to
a customer (or another division within the company) and is therefore called
Custody Transfer Metering. It forms the basis for invoicing the sold product
13
20. and also for production taxes and revenue sharing between partners and
accuracy requirements are often set by governmental authorities.
A metering installation typically consists of a number of meter runs so that
one meter will not have to handle the full capacity range, and associated
prover loops so that the meter accuracy can be tested and calibrated at
regular intervals.
Pipelines can measure
anywhere from 6 to 48
inches (15 – 120 cm) in
diameter. In order to
ensure their efficient
and safe operation,
operators routinely
inspect their pipelines
for corrosion and
defects. This is done
through the use of
sophisticated pieces of
equipment known as
pigs. Pigs are intelligent
robotic devices that are propelled down pipelines to evaluate the interior of
the pipe. Pigs can test pipe thickness, roundness, check for signs of
corrosion, detect minute leaks, and any other defect along the interior of the
pipeline that may either restrict the flow of gas, or pose a potential safety risk
for the operation of the pipeline. Sending a pig down a pipeline is fittingly
known as 'pigging' the pipeline. The export facility must contain equipment to
safely insert and retrieve pigs from the pipeline as well as depressurization,
referred to as pig launchers and pig receivers.
Loading on tankers involves loading systems, ranging from tanker jetties to
sophisticated single point mooring and loading systems that allow the tanker
to dock and load the product even in bad weather.
2.3 Utility systems
Utility systems are systems which do not handle the hydrocarbon process
flow, but provide some service to the main process safety or residents.
Depending on the location of the installation, many such functions may be
available from nearby infrastructure (e.g. electricity). But many remote
installations must be fully self-sustaining and must generate their own power,
water etc.
14
21. 3 Reservoir and wellheads
There are three main types of conventional wells. The most common is an oil
well with associated gas. Natural gas wells are drilled specifically for natural
gas, and contain little or no oil. Condensate wells contain natural gas, as well
as a liquid condensate. This condensate is a liquid hydrocarbon mixture that
is often separated from the natural gas either at the wellhead, or during the
processing of the natural gas. Depending on the type of well that is being
drilled, completion may differ slightly. It is important to remember that natural
gas, being lighter than air, will naturally rise to the surface of a well.
Consequently, lifting equipment and well treatment are not necessary in
many natural gas and condensate wells, while for oil wells many types of
artificial lift might be installed, particularly as the reservoir pressure falls
during years of production.
3.1 Crude oil and natural gas
3.1.1 Crude oil
Crude oil is a complex mixture consisting of 200 or more different organic
compounds, mostly alkenes (single bond hydrocarbons on the form CnH2n+2)
and smaller fraction aromatics (six-ring molecules such as benzene C6H6)
Different crude contains different combinations and concentrations of these
various compounds. The API (American Petroleum Institute) gravity of a
particular crude is merely a measure of its specific gravity, or density. The
higher the API number expressed as degrees API, the less dense (lighter,
15
22. thinner) the crude. This means, put simply, that the lower the degrees API,
the denser (heavier, thicker) the crude. Crude from different fields and from
different formations within a field can be similar in composition or be
significantly different.
In addition to API grade and hydrocarbons, crude is characterized for other
undesired elements like sulfur etc, which is regulated and needs to be
removed.
Crude oil API gravities typically range from 7 to 52 corresponding to about
970 kg/m3 to 750 kg/m3, but most fall in the 20 to 45 API gravity range.
Although light crude (i.e. 40-45 degrees API) is considered the best, lighter
crude (i.e., 46 degree API and above) is generally no better for a typical
refinery. As the crude gets lighter than 40-45 degrees API, it contains shorter
molecules, which means a lower carbon number. This also means it contains
less of the molecules useful as high octane gasoline and diesel fuel, the
production of which most refiners try to maximize. If a crude is heavier than
35 degree API, it contains longer and bigger molecules that are not useful as
high octane gasoline and diesel fuel without further processing.
For crude that has undergone detailed physical and chemical property
analysis, the API gravity can be used as a rough index of the quality of
crudes of similar composition as they naturally occur (that is, without
adulteration, mixing, blending, etc.). When crudes of a different type and
quality are mixed, or when different petroleum components are mixed, API
gravity cannot be used meaningfully for anything other than a measure of the
density of the fluid.
For instance,
consider a barrel of
tar that is dissolved in
3 barrels of naphtha
(lighter fluid) to
produce 4 barrels of
a 40 degree API
mixture. When this 4-
barrel mixture is fed
to a distillation
column at the inlet to
a refinery, one barrel
of tar plus 3 barrels of
naphtha is all that will
come out of the still.
16
23. On the other hand, 4 barrels of a naturally occurring 40 degree API crude fed
to the distillation column at the refinery, could come out of the still as 1.4
barrels of gasoline and naphtha (typically C8H18), 0.6 barrels of kerosene (jet
fuel C12-15 ), 0.7 barrels of diesel fuel (average C12H26), 0.5 barrels of heavy
distillate (C20-70), 0.3 barrels of lubricating stock, and 0.5 barrels of residue
(bitumen, mainly poly-cyclic aromatics).
The figure above to the right illustrates weight percent distributions of three
different hypothetical petroleum stocks that could be fed to a refinery with
catalytic cracking capacity. The chemical composition is generalized by the
carbon number which is the number of carbon atoms in each molecule -
CnH2n+2. A medium blend is desired because it has the composition that will
yield the highest output of high octane gasoline and diesel fuel in the
cracking refinery. Though the heavy stock and the light stock could be mixed
to produce a blend with the same API gravity as the medium stock, the
composition of the blend would be very different from the medium stock, as
the figure indicates. Heavy crude can be processed in a refinery by cracking
and reforming that reduces the carbon number to increase the high value
fuel yield.
3.1.2 Natural gas
The natural gas used by consumers is composed almost entirely of
methane. However, natural gas found at the wellhead, although still
composed primarily of methane, is not pure. Raw natural gas comes from
three types of wells: oil wells, gas wells, and condensate wells.
Natural gas that comes from oil wells is typically termed 'associated gas'.
This gas can exist separate from oil in the formation (free gas), or dissolved
in the crude oil (dissolved gas). Natural gas from gas and condensate wells,
in which there is little or no crude oil, is termed 'non-associated gas'.
Gas wells typically produce raw natural gas only. However condensate wells
produce free natural gas along with a semi-liquid hydrocarbon condensate.
Whatever the source of the natural gas, once separated from crude oil (if
present) it commonly exists in mixtures with other hydrocarbons, principally
ethane, propane, butane, and pentanes. In addition, raw natural gas
contains water vapor, hydrogen sulfide (H2S), carbon dioxide, helium,
nitrogen, and other compounds.
Natural gas processing consists of separating all of the various
hydrocarbons and fluids from the pure natural gas, to produce what is known
as 'pipeline quality' dry natural gas. Major transportation pipelines usually
17
24. impose restrictions on the composition of the natural gas that is allowed into
the pipeline and measure energy content in kJ/kg (also called calorific value
or Wobbe index).
3.1.3 Condensates
While the ethane, propane, butane, and pentanes must be removed from
natural gas, this does not mean that they are all 'waste products'. In fact,
associated hydrocarbons, known as 'natural gas liquids' (NGL) can be very
valuable by-products of natural gas processing. NGLs include ethane,
propane, butane, iso-butane, and natural gasoline. These are sold
separately and have a variety of different uses such as raw materials for oil
refineries or petrochemical plants, as sources of energy, and for enhancing
oil recovery in oil wells. Condensates are also useful as diluents for heavy
crude, see below.
3.2 The reservoir
The oil and gas bearing structure is typically of porous rock such as
sandstone or washed out limestone. The sand might have been laid down as
desert sand dunes or seafloor. Oil and gas deposits form as organic material
(tiny plants and animals) deposited in earlier geological periods, typically 100
to 200 million years ago, under, over or with the sand or silt, are transformed
by high temperature and pressure into hydrocarbons.
Anticline Fault Salt dome
Gas Porous rock
Oil Impermeable rock
Fossil water in porous reservoir rock
For an oil reservoir to form, porous rock needs to be covered by a non-
porous layer such as salt, shale, chalk or mud rock that can prevent the
18
25. hydrocarbons from leaking out of the structure. As rock structures become
folded and raised as a result of tectonic movements, the hydrocarbons
migrate out of the deposits and upward in porous rock and collect in crests
under the non-permeable rock, with gas at the top, then oil and fossil water
at the bottom. Salt is a thick fluid and if deposited under the reservoir will
flow up in heavier rock over millions of years. This creates salt domes with a
similar reservoir forming effect, and are common in the Middle East for
example.
This extraordinary process is still continuing. However, an oil reservoir
matures in the sense that an immature formation may not yet have allowed
the hydrocarbons to form and collect. A young reservoir generally has heavy
crude, less than 20 API, and is often Cretaceous in origin (65-145 million
years ago). Most light crude reservoirs tend to be Jurassic or Triassic (145-
205/205-250 million years ago) and gas reservoirs where the organic
molecules are further broken down are often Permian or Carboniferous in
origin (250-290/290-350 million years ago).
In some areas, strong uplift, erosion and cracking of rock above have
allowed the hydrocarbons to leak out, leaving heavy oil reservoirs or tar
pools. Some of the world's largest oil deposits are tar sands, where the
volatile compounds have evaporated from shallow sandy formations leaving
huge volumes of bitumen-soaked sands. These are often exposed at the
surface and can be strip-mined, but must be
separated from the sand with hot water, 101 kPa
10 °C
steam and diluents and further processed with
cracking and reforming in a refinery to
improve fuel yield.
The oil and gas is pressurized in the pores of
the absorbent formation rock. When a well is
drilled into the reservoir structure, the
hydrostatic formation pressure drives the Gas expands
hydrocarbons out of the rock and up into the 20 MPa
100 °C and pushes oil
well. When the well flows, gas, oil and water downwards
is extracted, and the levels will shift as the
reservoir is depleted. The challenge is to plan
drilling so that reservoir utilization can be
maximized. 40 MPa
200 °C
Seismic data and advanced 3D visualization
models are used to plan extraction. Even so,
the average recovery rate is only 40%, Reservoir hydrostatic pressure
pushes oil and gas upwards.
19
26. leaving 60% of the hydrocarbons trapped in the reservoir. The best
reservoirs with advanced Enhanced Oil Recovery (EOR) allow up to 70%.
Reservoirs can be quite complex, with many folds and several layers of
hydrocarbon-bearing rock above each other (in some areas more than 10).
Modern wells are drilled with large horizontal offsets to reach different parts
of the structure and with multiple completions so that one well can produce
from several locations.
3.3 Exploration and drilling
When 3D seismic investigation
has been completed, it is time to
drill the well. Normally, dedicated
drilling rigs either on mobile
onshore units or offshore floating
rigs are used. Larger production
platforms may also have their
own production drilling
equipment. Photo: Puna Geothermal
Venture
The main components of the
drilling rig are the derrick, floor,
drawworks, drive and mud handling. The control and power can be hydraulic
or electric.
Earlier pictures of drillers and roughnecks working with rotary tables (bottom
drives) are now replaced with top drive and semi-automated pipe handling
on larger installations. The hydraulic or electric top drive hangs from the
derrick crown and gives pressure and rotational torque to the drill string. The
whole assembly is controlled by the drawworks.
The drill string is assembled
from pipe segments about 30
meters (100 feet) long
normally with conical inside
threads at one end and
outside at the other. As each
30 meter segment is drilled,
the drive is disconnected and
a new pipe segment inserted
in the string. A cone bit is
used to dig into the rock.
20
27. Different cones are used for different types of rock and at different stages of
the well. The picture shows roller cones with inserts (on the left). Other bits
are PDC (polycrystalline diamond compact, on the right) and diamond
impregnated. Photo: Kingdream PLC
As the well is sunk into the ground, the weight of the drill string increases
and might reach 500 metric tons or more for a 3000 meter deep well. The
drawwork and top drive must be precisely controlled so as not to overload
and break the drill string or the cone. Typical values are 50kN force on the
bit and a torque of 1-1.5 kNm at 40-80 RPM for an 8 inch cone. ROP (Rate
of Penetration) is very dependant on depth and could be as much as 20
meters per hour for shallow sandstone and dolomite (chalk) and as low as 1
m/hour on deep shale rock and granite.
Directional drilling is
intentional deviation of a
well bore from the
vertical. It is often
necessary to drill at an
angle from the vertical to
reach different parts of
the formation. Controlled
directional drilling makes
it possible to reach
subsurface areas
laterally remote from the
point where the bit enters
the earth. It often
involves the use of a drill
motor driven by mud pressure mounted directly on the cone (mud motor,
turbo drill, and dyna-drill), whipstocks - a steel casing that will bend between
the drill pipe and cone, or other deflecting rods, also used for horizontal wells
and multiple completions, where one well may split into several bores. A well
which has sections of more than 80 degrees from the vertical is called a
horizontal well. Modern wells are drilled with large horizontal offsets to reach
different parts of the structure and achieve higher production. The world
record is more than 15 kilometers. Multiple completions allow production
from several locations.
Wells can be of any depth from near the surface to a depth of more than
6000 meters. Oil and gas are typically formed at 3000-4000 meters depth,
but part of the overlying rock can since have eroded away. The pressure and
temperature generally increase with increasing depth, so that deep wells can
21
28. have more than 200 C temperature and 90 MPa pressure (900 times
atmospheric pressure), equivalent to the hydrostatic pressure set by the
distance to the surface. The weight of the oil in the production string reduces
wellhead pressure. Crude oil has a specific weight of 790 to 970 kg per cubic
meter. For a 3000 meter deep well with 30 MPa downhole pressure and
normal crude oil at 850 kg/m3, the wellhead static pressure will only be
around 4.5 MPa. During production, the pressure will drop further due
resistance to flow in the reservoir and well.
The mud enters though the drill pipe, passes through the cone and rises in
the uncompleted well. Mud serves several purposes:
• It brings rock shales (fragments of rock) up to the surface
• It cleans and cools the cone
• It lubricates the drill pipe string and Cone
• Fibrous particles attach to the well surface to bind solids
• Mud weight should balance the downhole pressure to avoid leakage
of gas and oil. Often, the well will drill though smaller pockets of
hydrocarbons which may cause "a blow-out" if the mud weight
cannot balance the pressure. The same might happen when drilling
into the main reservoir.
To prevent an uncontrolled blow-out, a subsurface safety valve is often
installed. This valve has enough closing force to seal off the well and cut the
drill string in an uncontrollable blow-out situation. However, unless casing is
already also in place, hydrocarbons may also leave though other cracks
inside the well and rise to the surface through porous or cracked rock. In
addition to fire and pollution hazards, dissolved gas in seawater rising under
a floating structure significantly reduces buoyancy.
The mud mix is a
specialist brew
designed to match the
desired flow thickness,
lubrication properties
and specific gravity.
Mud is a common
name used for all kinds
of fluids used in drilling
completion and
workover and can be oil
based, water based or
synthetic, and consists
22
29. of powdered clays such as bentonite, oil, water and various additives and
chemicals such as caustic soda, barite (sulfurous mineral), lignite (brown
coal), polymers and emulsifiers. Photo: OSHA.gov
A special high density mud called Kill Fluid is used to shut down a well for
workover.
Mud is recirculated. Coarse rock shales are separated in a shale shaker
before it is passed though finer filters and recalibrated with new additives
before returning to the mud holding tanks
3.4 The well
When the well has been drilled, it must be completed. Completing a well
consists of a number of steps, such as installing the well casing, completion,
installing the wellhead, and installing lifting equipment or treating the
formation should that be required.
3.4.1 Well casing
Installing the well casing is an important part of the drilling and completion
process. Well casing consists of a series of metal tubes installed in the
freshly drilled hole. Casing serves to strengthen the sides of the well hole,
ensure that no oil or natural gas seeps out as it is brought to the surface, and
to keep other fluids or gases from seeping into the formation through the
well. A good deal of planning is necessary to ensure that the right casing for
each well is installed. Types of casing used depend on the subsurface
characteristics of the
well, including the
diameter of the well
(which is dependent
on the size of the drill
bit used) and the
pressures and
temperatures
experienced. In most
wells, the diameter of
the well hole
decreases the deeper
it is drilled, leading to
a type of conical
shape that must be
taken into account
23
30. when installing casing. The casing is normally cemented in place. Ill:
wikipedia.org
There are five different types of well casing. They include:
• Conductor casing, which is usually no more than 20 to 50 feet (7-17
meter) long, installed before main drilling to prevent the top of the
well from caving in and to help in the process of circulating the
drilling fluid up from the bottom of the well.
• Surface casing is the next type of casing to be installed. It can be
anywhere from 100 to 400 meters long, and is smaller in diameter to
fit inside the conductor casing. Its primary purpose is to protect fresh
water deposits near the surface of the well from being contaminated
by leaking hydrocarbons or salt water from deeper underground. It
also serves as a conduit for drilling mud returning to the surface and
helps protect the drill hole from being damaged during drilling.
• Intermediate casing is usually the longest section of casing found in
a well. Its primary purpose is to minimize the hazards associated
with subsurface formations that may affect the well. These include
abnormal underground pressure zones, underground shales and
formations that might otherwise contaminate the well, such as
underground salt water deposits. Liner strings are sometimes used
instead of intermediate casing. Liner strings are usually just attached
to the previous casing with 'hangers', instead of being cemented into
place and are thus less permanent.
• Production casing, alternatively called the 'oil string' or 'long string',
is installed last and is the deepest section of casing in a well. This is
the casing that provides a conduit from the surface of the well to the
petroleum producing formation. The size of the production casing
depends on a number of considerations, including the lifting
equipment to be used, the number of completions required, and the
possibility of deepening the well at a later date. For example, if it is
expected that the well will be deepened later, then the production
casing must be wide enough to allow the passage of a drill bit later
on. It is also instrumental in preventing blow-outs, allowing the
formation to be 'sealed' from the top should dangerous pressure
levels be reached.
Once the casing is installed, tubing is inserted inside the casing, from the
opening well at the top, to the formation at the bottom. The hydrocarbons
that are extracted run up this tubing to the surface. The production casing is
24
31. typically 5 to 28 cm (2 -11 in.) with most production wells being 6 inches or
more. Production depends on reservoir, bore, pressure etc. and could be
less than 100 barrels a day to several thousand barrels per day. (5000 bpd is
about 555 liters/minute). A packer is used between casing and tubing at the
bottom of the well.
3.4.2 Completion
Well completion commonly refers to the process of finishing a well so that it
is ready to produce oil or natural gas. In essence, completion consists of
deciding on the characteristics of the intake portion of the well in the targeted
hydrocarbon formation. There are a number of types of completions,
including:
• Open hole completions are the most basic type and are only used in
very competent formations, which are unlikely to cave in. An open
hole completion consists of simply running the casing directly down
into the formation, leaving the end of the piping open without any
other protective filter.
• Conventional perforated completions consist of production casing
run through the formation. The sides of this casing are perforated,
with tiny holes along the sides facing the formation, which allows
hydrocarbons to flow into the well hole but still provides a suitable
amount of support and protection for the well hole. In the past, 'bullet
perforators' were used. These were essentially small guns lowered
into the well that sent off small bullets to penetrate the casing and
cement. Today, 'jet perforating' is preferred. This consists of small,
electrically-fired charges that are lowered into the well. When ignited,
these charges poke tiny holes through to the formation, in the same
manner as bullet perforating.
• Sand exclusion completions are designed for production in an area
that contains a large amount of loose sand. These completions are
designed to allow for the flow of natural gas and oil into the well, but
at the same time prevent sand from entering. The most common
methods of keeping sand out of the well hole are screening, or
filtering systems. Both of these types of sand barriers can be used in
open hole and perforated completions.
• Permanent completions are those in which the completion and
wellhead are assembled and installed only once. Installing the
casing, cementing, perforating, and other completion work is done
with small diameter tools to ensure the permanent nature of the
25
32. completion. Completing a well in this manner can lead to significant
cost savings compared to other types
• Multiple zone completion is the practice of completing a well such
that hydrocarbons from two or more formations may be produced
simultaneously, without mixing with each other. For example, a well
may be drilled that passes through a number of formations on its
way deeper underground, or it may be more desirable in a horizontal
well to add multiple completions to drain the formation most
effectively. When it is necessary to separate different completions,
hard rubber 'packing' instruments are used to maintain separation.
• Drainhole completions are a form of horizontal or slanted drilling.
This type of completion consists of drilling out horizontally into the
formation from a vertical well, essentially providing a 'drain' for the
hydrocarbons to run down into the well. These completions are more
commonly associated with oil wells than with natural gas wells.
3.5 Wellhead
Wellheads can involve dry or subsea
completion. Dry completion means
that the well is onshore or on the
topside structure on an offshore
installation. Subsea wellheads are
located under water on a special sea
bed template.
The wellhead has equipment
mounted at the opening of the well to
regulate and monitor the extraction of
hydrocarbons from the underground
formation. This also prevents oil or
natural gas leaking out of the well,
and prevents blow-outs due to high
pressure formations. Formations that
are under high pressure typically
require wellheads that can withstand
a great deal of upward pressure from
the escaping gases and liquids.
These must be able to withstand
pressures of up to 140 MPa (1400
Bar). The wellhead consists of three
26
33. components: the casing head, the tubing head, and the 'Christmas tree'
Photo: Vetco Gray
A typical Christmas tree
composed of a master gate
valve, a pressure gauge, a
wing valve, a swab valve and
a choke is shown here. The
Christmas tree may also
have a number of check
valves. The functions of
these devices are explained
in the following paragraphs.
Ill: Vetco Gray
At the bottom we find the
casing head and casing
hangers.
The casing will be screwed,
bolted or welded to the
hanger. Several valves and
plugs will normally be fitted to
give access to the casing.
This will permit the casing to
be opened, closed, bled
down, and in some cases,
allow the flowing well to be
produced through the casing
as well as the tubing. The
valve can be used to
determine leaks in casing,
tubing or the packer, and will also be used for lift gas injection into the
casing.
The tubing hanger (also called a donut) is used to position the tubing
correctly in the well. Sealing also allows Christmas tree removal with
pressure in the casing.
Master gate valve. The master gate valve is a high quality valve. It provides
full opening, which means that it opens to the same inside diameter as the
tubing so that specialized tools may be run through it. It must be capable of
holding the full pressure of the well safely for all anticipated purposes. This
valve is usually left fully open and is not used to control flow.
27
34. The pressure gauge. The minimum instrumentation is a pressure gauge
placed above the master gate valve before the wing valve. In addition other
instruments such as a temperature gauge will normally be fitted.
The wing valve. The wing valve can be a gate or ball valve. When shutting
in the well, the wing gate or valve is normally used so that the tubing
pressure can be easily read.
The swab valve. The swab valve is used to gain access to the well for
wireline operations, intervention and other workover procedures (see below).
On top of it is a tree adapter and cap that will mate with a range of
equipment.
The variable flow choke valve. The variable flow choke valve is typically a
large needle valve. Its calibrated opening is adjustable in 1/64 inch
increments (called beans). High-quality steel is used in order to withstand
the high-speed flow of abrasive materials that pass through the choke,
usually over many years, with little damage except to the dart or seat. If a
variable choke is not required, a less expensive positive choke is normally
installed on smaller wells. This has a built-in restriction that limits flow when
the wing valve is fully open.
This is a vertical tree. Christmas trees can also be horizontal, where the
master, wing and choke are on a horizontal axis. This reduces the height
and may allow easier intervention. Horizontal trees are especially used on
subsea wells.
3.5.1 Subsea wells
Subsea wells are essentially the
same as dry completion wells.
Mechanically however, they are
placed in a subsea structure
(template) that allows the wells to
be drilled and serviced remotely
from the surface, and protected
from damage e.g. from trawlers.
The wellhead is placed in a slot
in the template where it mates to
the outgoing pipeline as well as
hydraulic and electric control signals. Ill: StatoilHydro
28
35. Control is from the
surface where a
hydraulic power unit
(HPU) provides power to
the subsea installation
via an umbilical. The
umbilical is a composite
cable containing tension
wires, hydraulic pipes,
electrical power, control
and communication
signals. A control pod
with inert gas and/or oil protection contains control electronics, and operates
most equipment via hydraulic switches. More complex subsea solutions may
contain subsea separation/stabilization and electrical multiphase pumping.
This may be necessary if reservoir pressure is low, offset (distance to main
facility) is long or there are flow assurance problems so that the gas and
liquids will not stably flow to the surface.
The product is piped back through pipelines and risers to the surface. The
main choke may be located topside.
3.5.2 Injection
Wells are also divided into production and injection wells. The former are for
production of oil and gas. Injection wells are drilled to inject gas or water into
the reservoir. The purpose of injection is to maintain overall and hydrostatic
reservoir pressure and force the oil toward the production wells. When
injected water reaches the production well, it is called 'injected water
breakthrough'. Special logging instruments, often based on radioactive
isotopes added to injection water, are used to detect breakthrough.
Injection wells are fundamentally the same as production wellheads The
difference being their direction of flow and therefore mounting of some
directional components such as the choke.
3.6 Artificial lift
Production wells are free flowing or lifted. A free flowing oil well has enough
downhole pressure to reach suitable wellhead production pressure and
maintain an acceptable well-flow. If the formation pressure is too low, and
29
36. water or gas injection cannot maintain pressure or are not suitable, the well
must be artificially lifted. For smaller wells, 0.7 MPa (100 PSI) wellhead
pressure with a standing column of liquid in the tubing is measured, by a
rule-of-thumb method, to allow the well to flow. Larger wells will be equipped
with artificial lift to increase production even at much higher pressures. Some
artificial lift methods are:
3.6.1 Rod pumps
Sucker rod pumps, also called donkey or beam pumps, are the most
common artificial-lift system used in land-based operations. A motor drives a
reciprocating beam, connected to a polished rod passing into the tubing via a
stuffing box. The sucker rod continues down to the oil level and is connected
to a plunger with a valve.
On each
upward stroke,
the plunger lifts
a volume of oil
up and through
the wellhead
discharge. On
the downward
stroke it sinks
(it should sink,
and not be
pushed) allowing oil to flow though the valve. The motor speed and torque is
controlled for efficiency and
minimal wear with a Pump
off Controller (PoC). Use is
limited to shallow
reservoirs down to a few
hundred meters, and flows
up to about 40 liters (10
gal) per stroke.
3.6.2 Downhole
pumps
A downhole pump inserts
the whole pumping
mechanism into the well. In
30
37. modern installations, an Electrical Submerged Pump (ESP) is inserted into
the well. Here the whole assembly consisting of a long narrow motor and a
multi phase pump, such as a PCP (progressive cavity pump) or centrifugal
pump, hangs by an electrical cable with tension members down the tubing. Ill:
Wikipedia.org
Installations down to 3.7 km with power up to 750 kW have been installed. At
these depths and power ratings, medium voltage drives (up to 5kV) must be
used.
ESPs work in deep reservoirs, but are sensitive to contaminants such as
sand, and efficiency is sensitive to GOR (Gas Oil Ratio) where gas over 10%
dramatically lowers efficiency.
3.6.3 Gas lift
A gas lift injects gas into
the well flow. The
downhole reservoir
pressure falls off to the
wellhead due to the
counter pressure from
weight of the oil column in
the tubing. Thus a 150
MPa reservoir pressure at
1600 meters will fall to
zero in the wellhead if the
specific gravity is 800
kg/m2. (0.8 times water).
By injecting gas into this
oil, the specific gravity is
lowered and the well will
start to flow. Typically gas
injected between the
casing and tubing, and a
release valve on a gas lift
mandrel is inserted into
the tubing above the packer.
The valve will open at a set pressure to inject lift gas into the tubing. Several
mandrels with valves set at different pressure ranges can be used to
improve lifting and startup. Ill: Schlumberger oilfield glossary
31
38. Gas lift can be controlled for a single well to optimize production, and to
reduce slugging effects where the gas droplets collect to form large bubbles
that can upset production. Gas lift can also be optimized over several wells
to use available gas in the most efficient way.
3.6.4 Plunger lift
The Plunger lift is normally used on low pressure gas wells with some
condensate, oil or water, or high gas ratio oil wells. In this case the well flow
conditions can be such that liquid starts to collect downhole and eventually
blocks gas so that the well production stops. In this case a plunger with an
open/close valve can be inserted in the tubing. A plunger catcher at the top
opens the valve and can hold the plunger, while another mechanism
downhole will close the valve.
The cycle starts with
the plunger falling
into the well with its
valve open.
Condensed gas and
oil can pass though
the plunger until it
reaches bottom.
There the valve is
closed, now with a
volume of oil,
condensate or water
on top. Gas pressure
starts to accumulate
under the plunger
and after a time
pushes the plunger
upwards, with liquid
on top, which
eventually flows out
of the wellhead
discharge.
When the plunger
reaches the wellhead plunger catcher, the valve opens and allows gas to
flow freely for some time while new liquid collects at the bottom. After a
preset time the catcher will release the plunger and the cycle repeats.
32
39. 3.7 Well workover, intervention and stimulation.
After operating for some time, a well may become less productive or faulty
due to residue build up, sand erosion, corrosion or reservoir clogging.
Well workover is the process of performing major maintenance on an oil or
gas well. This might include replacement of the tubing, a cleanup or new
completions, new perforations and various other maintenance works such as
the installation of gas lift mandrels, new packing etc.
Through-tubing workover operation is work performed with special tools that
do not require the time-consuming full workover procedure including
replacement or removal of tubing. Well maintenance without killing the well
and performing full workover is time-saving and often called well
intervention. Various operations that are performed by lowering instruments
or tools on a wire into the well are called wireline operations.
Work on the reservoir such as chemical injection, acid treatment, heating etc
is referred to as reservoir stimulation. Stimulation serves to correct various
forms of structure damage and improve flow. Damage is a generic term for
accumulation of particles and fluids that block fractures and pores and limit
reservoir permeability.
• Acids, such as HCL (Hydrochloric Acid) are used to open up
calcareous reservoirs and to treat accumulation of calcium
carbonates in the reservoir structure around the well. Several
hundred liters of acid (typically 15% solution in water) are pumped
into the well under pressure to increase permeability of the
formation. When the pressure is high enough to open the fractures,
the process is called fracture acidizing. If the pressure is lower, it is
called matrix acidizing.
• Hydraulic fracturing is an operation in which a specially blended
liquid is pumped down a well and into a formation under pressure
high enough to cause the formation to crack open, forming passages
through which oil can flow into the well bore. Sand grains, aluminum
pellets, walnut shells, glass beads, or similar materials (propping
agents) are carried in suspension by this fluid into the fractures.
When the pressure is released at the surface, the fractures partially
close on the propping agents, leaving channels for oil to flow through
to the well. The fracture channels may be up to 100 meters long.
• Explosive fracturing uses explosives to fracture a formation. At the
moment of detonation, the explosion furnishes a source of high-
33
40. pressure gas to force fluid into the formation. The rubble prevents
fracture healing, making the use of propping agents unnecessary.
• Damage removal refers to other forms of removing formation
damage, such as flushing out of drill fluids.
Flexible coiled tubing can be wound around a large diameter drum and
inserted or removed much quicker than tubing installed from rigid pipe
segments. Well workover equipment including coiled tubing is often mounted
on well workover rigs.
34
41. 4 The oil and gas process
The oil and gas process is the process equipment that takes the product
from the wellhead manifolds and delivers stabilized marketable products, in
the form of crude oil, condensates or gas. Components of the process also
exist to test products and clean waste products such as produced water.
An example process for
the Statoil Njord floater
is shown on the next
page. This is a medium
size platform with one
production train and a
production of 40-45,000
barrels per day (bpd).
This is actual
production, after the
separation of water and
gas. The associated
gas and water are used
for onboard power
generation and gas
reinjection. There is only one separation and gas compression train. The
water is treated and released (it could also have been reinjected). This
process is quite representative for hundreds of similar sized installations,
and only one more complete gas treatment train for gas export is missing to
form a complete gas production facility, Njord sends the oil via a short
pipeline to a nearby storage floater. On gravity base platforms, FPSO
(Floating Production and Storage Operations) and onshore plants this
storage will be a part of the main installation if the oil is not piped out directly.
Photo: Norsk Hydro ASA
A large number of connections to chemicals, flares etc. are shown, these
systems are described separately.
Nård main process illustration (next page): Statoil
35
43. 4.1 Manifolds and gathering
4.1.1 Pipelines and risers
This facility uses subsea production wells. The typical High Pressure (HP)
wellhead at the bottom right, with its Christmas tree and choke, is located on
the sea bed. A production riser (offshore) or gathering line (onshore) brings
the well flow into the manifolds. As the reservoir is produced, wells may fall
in pressure and become Low Pressure (LP) wells.
This line may include several check valves. The choke, master and wing
valves are relatively slow, therefore in the case of production shutdown, the
pressure on the first sectioning valve closed will rise to the maximum
wellhead pressure before these valves can close. The pipelines and risers
are designed with this in mind.
Short pipeline distances are not a problem, but longer distances may cause
a multiphase well flow to separate and form severe slugs - plugs of liquid
with gas in between - traveling in the pipeline. Severe slugging may upset
the separation process and cause overpressure safety shutdowns. Slugging
might also occur in the well as described earlier. Slugging can be controlled
manually by adjusting the choke, or by automatic slug controls. Furthermore,
areas of heavy condensate might form in the pipelines. At high pressure,
these plugs may freeze at normal sea temperature, e.g. if production is shut
down or with long offsets. This can be prevented by injecting ethylene glycol.
Glycol injection is not used at Njord.
The Njord floater has topside chokes for subsea wells. The diagram also
shows that Kill Fluid, essentially high specific gravity mud, can be injected
into the well before the choke.
4.1.2 Production, test and injection manifolds
Check valves allow each well to be routed into one or more of several
manifold lines. There will be at least one for each process train plus
additional manifolds for test and balancing purposes. In the diagram we
show three: test, low pressure and high pressure manifolds. The test
manifold allows one or more wells to be routed to the test separator. Since
there is only one process train, the HP and LP manifolds allow groups of HP
and LP wells to be taken to the first and second stage separators
respectively. The chokes are set to reduce the wellhead flow and pressure to
the desired HP and LP pressures respectively.
37
44. The desired setting for each well and which of the wells produce at HP and
LP for various production levels are defined by reservoir specialists to
ensure the optimum production and recovery rate.
4.2 Separation
As described earlier, the well-stream may consist of crude oil, gas,
condensates, water and various contaminants. The purpose of the
separators is to split the flow into desirable fractions.
4.2.1 Test separators and well test
Test separators are used to separate the well flow from one or more wells for
analysis and detailed flow measurement. In this way, the behavior of each
well under different pressure flow conditions can be defined. This normally
takes place when the well is taken into production and later at regular
intervals, typically 1-2 months and will measure the total and component flow
rates under different production conditions. Undesirable consequences such
as slugging or sand can also be determined. The separated components are
analyzed in the laboratory to determine hydrocarbon composition of the gas
oil and condensate.
Test separators can also be used to produce fuel gas for power generation
when the main process is
not running. Alternatively, a
three phase flow meter
could be used to save
weight.
4.2.2 Production
separators
The main separators shown
here are gravity types. On
the right you see the main
components around the first
stage separator. As
mentioned before, the
production choke reduces
well pressure to the HP
manifold and first stage
separator to about 3-5 MPa
38
45. (30-50 times atmospheric pressure). Inlet temperature is often in the range
of 100-150 degrees C. On the example platform, the well stream is colder
due to subsea wells and risers.
The pressure is often
reduced in several
stages, in this instance
three stages are used
to allow the controlled
separation of volatile
components. The idea
is to achieve maximum
liquid recovery and
stabilized oil and gas
and to separate water.
A large pressure
reduction in a single separator will cause flash vaporization leading to
instability and safety hazards.
The retention period is typically 5 minutes, allowing the gas to bubble out,
water to settle at the bottom and oil to be taken out in the middle. In this
platform the water cut (percentage water in the well flow) is almost 40%
which is quite high. In the first stage separator, the water content is typically
reduced to less than 5%.
At the crude entrance, there is a baffle slug catcher that will reduce the
effect of slugs (large gas bubbles or liquid plugs). However some turbulence
is desirable as this will release gas bubbles faster than a laminar flow.
At the end, there are barriers up to a certain level to keep back the
separated oil and water. The main control loops are the oil level control loop
(EV0101 20 above) controlling the oil flow out of the separator on the right,
and the gas pressure loop at the top.(FV0105 20 above) These loops are
operated by the Control System. An important function is also to prevent gas
blow-by which happens when a low oil level causes gas to exit via the oil
output causing high pressure downstream. There are generally many more
instruments and control devices mounted on the separator. These will be
discussed later.
The liquid outlets from the separator will be equipped with vortex breakers
to reduce disturbance on the liquid table inside. This is basically a flange trap
to break any vortex formation and ensure that only separated liquid is tapped
off and not mixed with oil or water drawn in though these vortices. Similarly
39
46. the gas outlets are equipped with demisters, essential filters that will
remove liquid droplets in the gas.
Emergency Valves (EV) are sectioning valves that will separate the process
components and blow-down valves, this will allows excess hydrocarbons to
be burned off in the flare. These valves are operated if critical operating
conditions are detected or on manual command, by a dedicated Emergency
Shutdown System. This might involve partial shutdown and shutdown
sequences since the flare might not be able to handle a full blow-down of all
process sections simultaneously.
A 45,000 bpd design production with gas and 40% water cut will give about
10 cubic meters from the wellheads per minute. There also needs to be
enough capacity to handle normal slugging from wells and risers. This
means the separator has to be about 100 cubic meters, e.g. a cylinder 3
meters in diameter and 14 meters in length at the rated operating pressure.
This means a very heavy piece of equipment, typically around 50 tons for
this size, which limits the practical number of stages. Other types of
separators such as vertical separators or cyclones (centrifugal separation)
can be used to save weight, space or improve separation (see later).
There also has to be a certain minimum pressure difference between each
stage to allow satisfactory performance in the pressure and level control
loops. Chemical additives will be discussed later.
4.2.3 Second stage separator
The second stage separator is quite similar to the first stage HP separator. In
addition to output from the first stage, it will also receive production from
wells connected to the Low Pressure manifold. The pressure is now around
1 MPa (10 atmospheres) and temperature below 100 degrees C. The water
content will be reduced to below 2%.
An oil heater could be located between the first and second stage separator
to reheat the oil/water/gas mixture. This will make it easier to separate out
water when initial water cut is high and temperature is low. The heat
exchanger is normally a tube/shell type where oil passes though tubes in a
heating medium placed inside an outer shell.
4.2.4 Third stage separator
The final separator here is a two-phase separator, also called a flash drum.
The pressure is now reduced to atmospheric pressure of around 100 kPa, so
that the last heavy gas components will boil out. In some processes where
40
47. the initial temperature is low, it might be necessary to heat the liquid (in a
heat exchanger) again before the flash drum to achieve good separation of
the heavy components. There are level and pressure control loops.
As an alternative, when the production is mainly gas, and remaining liquid
droplets have to be separated out, the two-phase separator can be a Knock-
Out Drum (K.O. Drum).
4.2.5 Coalescer
After the third stage separator, the oil can go to a coalescer for final removal
of water. In this unit the water content can be reduced to below 0.1%. The
coalescer is completely filled with liquid: water at the bottom and oil on top.
Internal electrodes form an electric field to break surface bonds between
conductive water and isolating oil in an oil water emulsion. The coalescer
field plates are generally steel, sometimes covered with dielectric material to
prevent short-circuits. The critical field strength in oil is in the range of 0.2 to
2 kV/cm. Field intensity and frequency as well as the coalescer grid layout
are different for different manufacturers and oil types.
4.2.6 Electrostatic desalter
If the separated oil
contains unacceptable
amounts of salts, they
can be removed in an
electrostatic desalter
(not used in the Njord
example) The salts,
which may be sodium,
calcium or magnesium
chlorides come from the reservoir water and are also dissolved in the oil.
The desalters will be placed after the first or second stage separator
depending on Gas Oil Ratio (GOR) and water cut. Photo: Burgess Manning Europe
PLC
4.2.7 Water treatment
On an installation such as this, where the water cut is high, there will be a
huge amount of water produced. In our example, a water cut of 40% gives
water production of about 4000 cubic meters per day (4 million liters) that
must be cleaned before discharge to sea. Often this water contains sand
particles bound to the oil/water emulsion.
41
48. The environmental regulations in most countries are quite strict, for example,
in the North-East Atlantic the OSPAR convention limits oil in water
discharged to sea to 40 mg/liter (ppm).
It also places limits on other forms of contaminants. This still means that the
equivalent of up to one barrel of oil per day in contaminants from the above
production is discharged into the sea, but in this form, the microscopic oil
drops are broken down fast by natural bacteria.
Various pieces of equipment are used. This illustration shows a typical water
treatment system. Water from the separators and coalescers first goes to a
sand cyclone, which removes most of the sand. The sand is further washed
before it is discharged.
The water then goes to a hydrocyclone, a centrifugal separator that will
remove oil drops. The hydrocyclone creates a standing vortex where oil
collects in the middle and water is forced to the side.
Finally the water is collected in the water de-gassing drum. Dispersed gas
will slowly rise to the surface and pull remaining oil droplets to the surface by
flotation. The surface oil film is drained, and the produced water can be
discharged to sea. Recovered oil in the water treatment system is typically
recycled to the third stage separator.
42
49. 4.3 Gas treatment and compression
The gas train consists of several stages, each taking gas from a suitable
pressure level in the production separator's gas outlet, and from the previous
stage.
A typical stage is
shown on the right.
Incoming gas (on
the right) is first
cooled in a heat
exchanger. It then
passes through the
scrubber to remove
liquids and goes
into the
compressor. The
anti surge loop
(thin orange line)
and the surge valve
(UV0121 23) allow
the gas to
recirculate. The components are described below.
4.3.1 Heat exchangers
For the compressor to operate efficiently, gas temperature should be low.
The lower the temperature, the less energy will be used to compress the gas
for the given final pressure
and temperature. However
both gas from separators
and compressed gas are
relatively hot. When gas is
compressed, it must remain
in thermodynamic balance,
which means that the gas
pressure times the volume
over the temperature
(PV/T) must remain
constant. (PV = nkT). This
ends up as a temperature
increase.
43
50. Heat exchangers of various forms are used to cool the gas. Plate heat
exchangers (upper picture) consist of a number of plates where the gas and
cooling medium pass between alternating plates in opposing directions.
Tube and shell exchangers (next picture) place tubes inside a shell filled with
of cooling fluid. The cooling fluid is often pure water with corrosion inhibitors.
When designing the
process, it is important to
plan the thermal energy
balance. Heat should be
conserved e.g. by using
the cooling fluid from the
gas train to reheat oil in the
oil train. Excess heat is
dispersed e.g. by seawater
cooling. However hot
seawater is extremely
corrosive, so materials with
high resistance to
corrosion, such as titanium
must be used. Photo: SEC
Shell and Tube Heat Exchanges
4.3.2 Scrubbers and reboilers
The separated gas may contain mist and other liquid droplets. Drops of
water and hydrocarbons also form when the gas is cooled in the heat
exchanger, and must be removed before it reaches the compressor. If liquid
droplets enter the compressor they will erode the fast rotating blades. A
scrubber is designed to remove small fractions of liquid from the gas.
There are various types of gas-drying equipment available, but the most
common suction (compressor) scrubber is based on dehydration by
absorption in Triethylene Glycol (TEG). The scrubber consists of many levels
of glycol layers.
A large number of gas traps (enlarged detail) force the gas to bubble up
through each glycol layer as it flows from the bottom up each section to the
top.
Processed glycol is pumped in at the top from the holding tank. It flows from
level to level against the gas flow as it spills over the edge of each trap.
During this process it absorbs liquids from the gas and comes out as rich
44
51. glycol at the bottom. The holding tank also functions as a heat exchanger for
liquid to and from the reboilers.
The glycol is recycled by removing the absorbed liquid. This is done in the
reboiler, which is filled with rich glycol and heated to boil out the liquids at
temperature of about 130-180 °C (260-350 °F) for a number of hours.
Usually there is a distillation column on the gas vent to further improve
separation of glycol and other hydrocarbons. For higher capacity, there are
often two reboilers which alternate between heating rich glycol and draining
recycled processed glycol.
On a standalone unit, the heat is supplied from a burner that uses the
recovered vaporized hydrocarbons. In other designs, heating will be a
combination of hot cooling substances from other parts of the process and
electric heaters, and recycle the hydrocarbon liquids to the third stage
separator
.
4.3.3 Compressor anti surge and performance
Several types of compressors are used for gas compression, each with
different characteristics such as operating power, speed, pressure and
volume:
45
52. • Reciprocating
compressors, which
use a piston and
cylinder design with
2-2 cylinders are
built up to about 30
MW power, around
500-1800 rpm (lower
for higher power)
with pressure up to
5MPa (500 bars).
Used for lower capacity gas compression and high reservoir pressure
gas injection. Photo: Ariel corp.
• Screw compressors are
manufactured up to
several MW, synchronous
speed (3000/3600 rpm)
and pressure up to about
2.5 MPa (25 bar). Two
counter-rotating screws
with matching profiles
provide positive
displacement and a wide
operating range. Typical
use is natural gas
gathering.
Photo: Mycom/Mayekawa mfg.
• Axial blade and fin type
compressors with up to
15 wheels provide high
volumes at relatively
low pressure differential
(discharge pressure 3-5
times inlet pressure),
speeds of 5000-8000
rpm, and inlet flows up
to 200,000 m3/hour.
Applications include air
compressors and cooling compression in LNG plants. Axial rotor photo:
Dresser Rand
46
53. • Larger oil and gas
installations use
centrifugal
compressors with 3-10
radial wheels, 6000–
20000 rpm (highest for
small size), up to 80
MW load at discharge
pressure of up to 50
bars and inlet volumes
of up to 500,000
m3/hour. Pressure
differential up to 10.
Photo: Dresser Rand
Most compressors will not
cover the full pressure range
efficiently. The lowest pressure is atmospheric, for gas to pipeline, some 3 to
5 MPa (30-50 bar) pressure is used, while reservoir reinjection of gas will
typically require 20 MPa (200 bar) and upwards since there is no liquid in the
tubing and the full reservoir pressure must be overcome. Therefore
compression is divided into several stages to improve maintenance and
availability.
Also due to single unit power limitations, compression is often divided in
several parallel trains. This is not the case in this example since gas is not
exported, and reinjection can be interrupted during maintenance periods.
Compressors are driven by gas turbines or electrical motors (for lower power
also reciprocating engines, steam turbines are sometimes used if thermal
energy is available). Often several stages in the same train are driven by the
same motor or turbine.
The main operating parameters for a compressor are the flow and pressure
differentials. The product defines the total loading, so there is a ceiling set by
the maximum design power. Furthermore, there is a maximum differential
pressure (Max Pd) and choke flow (Max Q), the maximum flow that can be
achieved. At lower flow, there is a minimum pressure differential and flow
before the compressor will "surge" if there is not enough gas to operate. If
variations in flow are expected or difference between common shaft
compressors will occur, the situation will be handled with recirculation. A
high flow, high pressure differential surge control valve will open to let gas
from the discharge side back into the suction side. Since this gas is heated it
will also pass through the heat exchanger and scrubber not to become
overheated by circulation.
47
54. The operating characteristics are defined by the manufacturer. In the above
diagram the blue lines mark constant speed lines. The maximum operating
limits are set by the orange line as described above. The surge domain is
the area to the left of the red surge curve.
The objective of compressor performance control is to keep the operating
point close to the optimal set point without violating the constraints, by
means of control outputs, such as the speed setting. However, gas turbine
speed control response is relatively slow and even electric motors are not
fast enough, since surge response must be in the 100 ms range. Anti surge
control will protect the compressor from going into surge by operating the
surge control valve. The basic strategy is to use distance between operating
point and surge line to control the valve with a slower response time starting
at the surge control line. Crossing the surge trip line will cause a fast
response opening of the surge valve to protect the compressor.
Operation with recirculation wastes energy (which could result in
unnecessary emissions) and produces wear and tear, particularly on the
surge valve. Each vendor supplies several variants of compressor control
and anti surge control to optimize performance, based on various corrective
and predictive algorithms. Some strategies include:
• Set point adjustment: If rapid variations in load cause surge valve
action, the set point will be moved to increase the surge margin.
48