Design of Atmospheric, Open-Bottom Mud/Gas Separators
Abstract: This paper will aid in sizing, material selection, installation, and operation of atmospheric open bottom mud gas separators (AOBMGS) for onshore well control operations. It is based on a document prepared for the Canadian Petroleum Association (CPA) entitled " Guidelines and Specifications for Designing Mud Gas Separators For Use In the Canadian Drilling Industry".1 Some modifications to the CPA document have been included in this paper.
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Cited by 5 publications
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SPE Member Abstract Conoco has developed generalized planning and training guidelines for well control on deep, high-pressure gas wells. These guidelines include a thorough review of gas behavior, causes of kicks, pressure indicators, and kick indicators as they pressure indicators, and kick indicators as they are applied to high-pressure gas wells. The guide-lines also emphasize the fundamentals associated with constant bottomhole pressure methods of well control. After the basic principles are reviewed, the characteristics of oil base mud are discussed. These characteristics are then related to all of the basic principles. Following this review, there is a practical example based on experiences Conoco had on a deep, high-pressure gas well drilled with oil base mud. Finally, there is the development of procedural and equipment requirements that are the procedural and equipment requirements that are the result of having systematically addressed well control principles for deep, high-pressure gas wells. Introduction Within the industry, there have been general concerns about how drilling with oil base mud affects the ability to detect and control kicks (references 1,2). This concern has become greater as oil base mud has become more commonly used for deep, high-pressure gas wells. There are three phenomena associated with oil base mud in phenomena associated with oil base mud in high-pressure gas wells that can have an effect on well control operations: Behavior of deep, high-pressure gas kicks Characteristics of heavily weighted oil mud in deep wells Gas solubility in oil Each of these alone can have a significant impact on kick prevention, kick detection, and well control. The impact becomes considerably greater as the three phenomena are combined. Conoco's progress on well control for deep, high-pressure gas wells, including those drilled with oil base mud (OBM), can be attributed to two principal activities: participation in two principal activities: participation in two Drilling Engineering Association (DEA) projects and detailed planning for drilling deep, high-pressure gas wells. As a result of these activities and plans to drill additional high pressure wells, Conoco is developing the technical approach and training requirements to address potential well control problems associated with high-pressure gas wells drilled with oil base mud. The principles and guidelines discussed in this paper have evolved from the work done for five wells, with planned TD's ranging from 15800 feet to 23000 feet. One of the objectives of this paper is to present a well control overview, parts of which can be used by research, parts of which can be used by research, engineering, or operations and the whole of which can result in safe, effective practices at the well site. Some of the concepts presented herein are no different for high-pressure gas wells than for any other drilling program, but they are included for completeness. Other concepts are discussed in greater detail to point out phenomena that could be important for a given well. Since effective well control is dependent on a combination of factors, this guide presents the basic principles and offers some examples of how their interactions can impact well control operations. This paper does not present recommendations that are universally applicable to deep, high-pressure wells. P. 665
SPE Member Abstract Conoco has developed generalized planning and training guidelines for well control on deep, high-pressure gas wells. These guidelines include a thorough review of gas behavior, causes of kicks, pressure indicators, and kick indicators as they pressure indicators, and kick indicators as they are applied to high-pressure gas wells. The guide-lines also emphasize the fundamentals associated with constant bottomhole pressure methods of well control. After the basic principles are reviewed, the characteristics of oil base mud are discussed. These characteristics are then related to all of the basic principles. Following this review, there is a practical example based on experiences Conoco had on a deep, high-pressure gas well drilled with oil base mud. Finally, there is the development of procedural and equipment requirements that are the procedural and equipment requirements that are the result of having systematically addressed well control principles for deep, high-pressure gas wells. Introduction Within the industry, there have been general concerns about how drilling with oil base mud affects the ability to detect and control kicks (references 1,2). This concern has become greater as oil base mud has become more commonly used for deep, high-pressure gas wells. There are three phenomena associated with oil base mud in phenomena associated with oil base mud in high-pressure gas wells that can have an effect on well control operations: Behavior of deep, high-pressure gas kicks Characteristics of heavily weighted oil mud in deep wells Gas solubility in oil Each of these alone can have a significant impact on kick prevention, kick detection, and well control. The impact becomes considerably greater as the three phenomena are combined. Conoco's progress on well control for deep, high-pressure gas wells, including those drilled with oil base mud (OBM), can be attributed to two principal activities: participation in two principal activities: participation in two Drilling Engineering Association (DEA) projects and detailed planning for drilling deep, high-pressure gas wells. As a result of these activities and plans to drill additional high pressure wells, Conoco is developing the technical approach and training requirements to address potential well control problems associated with high-pressure gas wells drilled with oil base mud. The principles and guidelines discussed in this paper have evolved from the work done for five wells, with planned TD's ranging from 15800 feet to 23000 feet. One of the objectives of this paper is to present a well control overview, parts of which can be used by research, parts of which can be used by research, engineering, or operations and the whole of which can result in safe, effective practices at the well site. Some of the concepts presented herein are no different for high-pressure gas wells than for any other drilling program, but they are included for completeness. Other concepts are discussed in greater detail to point out phenomena that could be important for a given well. Since effective well control is dependent on a combination of factors, this guide presents the basic principles and offers some examples of how their interactions can impact well control operations. This paper does not present recommendations that are universally applicable to deep, high-pressure wells. P. 665
Recent wellsite disasters have led to an increased emphasis on properly sized mud/gas separators. This paper reviews and analyzes existing mud/gas separator technology and recommends separator configuration, components, design considerations, and a sizing procedure. A simple method of evaluating mud/gas separation within the separator vessel has been developed as a basis for the sizing procedure. A mud/gas separator sizing worksheet will assist drilling personnel with the sizing calculations. The worksheet provides a quick and easy evaluation of most mud/gas separators for a specific well application. A brief discussion of other mud/gas separator considerations is provided, including separator components, testing, materials, and oil-based-mud considerations. IntroductionThe mud/gas separator is designed to provide effective separation of the mud and gas circulated from the well by venting the gas and returning the mud to the mud pits. Small amounts of entrained gas can then be handled by a vacuum-type degasser located in the mud pits. The mud/gas separator controls gas cutting during kick situations, during drilling with significant drilled gas in the mud returns, or when trip gas is circulated up.This paper discusses design considerations for mud/gas separators. The purpose of this paper is to allow drilling rig supervisors to evaluate mud/gas separators properly and to upgrade (if required) the separator economically to meet the design criteria outlined in this paper, and to provide office drilling personnel with guidelines for designing mud/gas separators before delivery at the drillsite.
Mud-Gas Separator Analysis: A Comprehensive Review of Sizing, Design Criteria, and Industry Standards
The Mud-Gas Separator (MGS) is a critical component in well control for handling gas kicks. It is the primary device for separating liquid-gas mixtures in most well control events. Poor separator designs and inefficient separation of gases from liquids in the MGS have resulted in the loss of lives and equipment and adverse environmental effects. Thus, the safe and efficient separation of gases from gas-cut drilling fluids in the MGS is vital. The design and operational efficiency of the MGS depend on certain key elements in its sizing, such as the vent line length and diameter, vessel internal diameter, hydrostatic head of the mud seal, and the vent line back pressure, amongst others. These design considerations and the industrial standards and regulations governing them are hitherto not fully understood. As a result, there is an associated risk in the operation of the MGS. This paper aims to comprehensively review and analyze key sizing and design considerations for the Mud Gas Separator for both Conventional and Managed Pressure Drilling Operations. Furthermore, industry standards, best practices, guidelines, and regulations on MGS design and operations are also reviewed. This study uses two primary methodologies: an extensive literature review and a stakeholder engagement consultation to meet the stipulated objectives. The results indicate that the sizing and design of MGS depend on various factors such as well depth, pressure and temperature regimes, formation fluid, and completion fluid systems. The study's outcomes also indicate that existing industry standards and regulations provide sufficient guidelines for various sizing and design considerations. The study also presents an analysis of existing industry recommendations on MGS design and sizing for special wellbore conditions, formation properties, and unconventional drilling applications like managed pressure drilling (MPD). The study provides further understanding of the MGS sizing and design from industry stakeholders’ perspective to minimize well-control risks associated with MGS.
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