Managing climate change adaptation in oil and gas production

2015 ◽  
Vol 55 (2) ◽  
pp. 456
Author(s):  
Paul van der Beeke
Keyword(s):  
Climate Change ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Business Case ◽  
Climatic Conditions ◽  
Gas Production ◽  
Extreme Weather Events ◽  
Oil And Gas Production ◽  
Climate Change Effects ◽  
Operational Life

Oil and gas production operations occur in widely diverse onshore and offshore contexts. The global industry has a long history of coping with climate variability, extreme climatic conditions and extreme weather events. Climate change, however, is projected to take the new climate beyond the range of historical variability in many places where oil and gas production facilities are located. Oil and gas infrastructure often has an expected operational life of 50 years or more, which would take new operations to 2064 and beyond. This is well inside the timeframe predicted for substantial climate change with consequent risks to longer term operational continuity and supply chain security. In recent years, the realities of climate change beyond pre-industrial age historical variability, and the associated business risks, have become accepted by the major global oil and gas industry players. Other stakeholders, including corporate, institutional and private investors and corporate regulators, are also becoming more assertive in their demands for corporate disclosure of climate change risks, adaptation management plans and evidence of effective implementation of adaptive measures. Industry decision-makers need scientifically sound and robust data applied to their specific operations and business conditions to support business case-based investment decisions for new project feasibility, capital and operational expenditure, and the management of long-term strategic liabilities. This extended abstract provides an overview of the complex and interconnected web of climate change effects that should be considered. It also outlines approaches that could be employed to manage the risks and meet stakeholder expectations.

On Approaches to Taking into Account the Risks of Changing Climatic Conditions when Planning and Implementing Oil and Gas Projects

2021 ◽  
Vol 18 (1) ◽  
pp. 52-65
Author(s):  
P. N. Mikheev
Keyword(s):  
Climate Change ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Climatic Conditions ◽  
Qualitative Assessment ◽  
Physical Factors ◽  
Gas Industry ◽  
Climate Risks ◽  
The Impact

The article discusses issues related to the impact of climate change on the objects of the oil and gas industry. The main trends in climate change on a global and regional (on the territory of Russian Federation) scale are outlined. Possible approaches to the identification and assessment of climate risks are discussed. The role of climatic risks as physical factors at various stages of development and implementation of oil and gas projects is shown. Based on the example of oil and gas facilities in the Tomsk region, a qualitative assessment of the level of potential risk from a weather and climatic perspective is given. Approaches to creating a risk management and adaptation system to climate change are presented.

A Step Change in the Digital Oilfield Arena: Cloud Computing and Workflow Integration for Production Operations Solutions

2021 ◽  
Author(s):  
Aditya Kotiyal ◽  
Guru Prasad Nagaraj ◽  
Lester Tugung Michael
Keyword(s):  
Oil And Gas ◽  
Dimensional Change ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
System Stability ◽  
Production Data ◽  
Oil And Gas Production ◽  
Common Domain ◽  
Digital Oilfield ◽  
Workflow Orchestration

Abstract Digital oilfield applications have been implemented in numerous operating companies to streamline processes and automate workflows to optimize oil and gas production in real-time. These applications are mostly deployed using traditional on-premises systems; where maintenance, accessibility and scalability serves as a major bottleneck for an efficient outcome. In addition to this challenge, the sector still faces limitations in data integration from disparate data sources, liberation of consolidated data for consumption and cross domain workflow orchestration of that data. The dimensional change brought by digital transformation strategies has paved a path for the Cloud- based solutions, which have recently gained momentum in the oil and gas industry pertaining to their wider accessibility, simpler customization, greater system stability and scalability to support larger amount of data in a performant way. To address the challenges mentioned earlier, we have embarked on a journey with Production Data Foundation which brings together production and equipment data from across an organization. In this paper, we will highlight how Production Data Foundation, hosted on the cloud, provides the underlying infrastructure, services, interfaces required to support and unify production data ingestion, workflow orchestration, and through the alignment of the common domain and digital concepts, improve collaboration between people in distinct roles, such as production engineers, reservoir engineers, drilling engineers, deployment engineers, software developers, data scientists, architects, and subject matter experts (SME) working with production operations products and solutions.

STUDY OF CHEMICAL REAGENTS AGAINST CORROSION PROCESSES IN THE CONDITIONS OF THE UZEN FIELD

2021 ◽  
Vol 73 (1) ◽  
pp. 185-195
Author(s):  
U. Zh. Tazhenbayeva ◽  
◽  
Ye.O. Ayapbergenov ◽  
G. Zh. Yeligbayeva ◽  
◽  
...  
Keyword(s):  
Corrosion Inhibitors ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Freezing Temperature ◽  
Gas Production ◽  
Localized Corrosion ◽  
Laboratory Research ◽  
Oil And Gas Production ◽  
Field Equipment ◽  
Long Run

One of the biggest challenges in oil and gas production projects is dealing with the various types of corrosion to which certain parts of field equipment are exposed. Selecting the right corrosion inhibitor for the specific environment is extremely important. Choosing inhibitors for a particular location can be a difficult task because there are many factors to be considered. Understanding the corrosion problems that can arise is important in the oil and gas industry, and knowledge of which inhibitors to use to deal with general and localized corrosion will save time and money in the long run. This article presents the results of studies of various brands of domestic and foreign corrosion inhibitors for use in the Uzen field: physical and chemical characteristics (density, viscosity, freezing temperature, mass fraction of active substance, compatibility with field waters, amine number), efficiency of corrosion inhibitors in laboratory conditions and on a bench simulating field reservoir conditions, taking into account pressure, temperature, fluid flow rate, as well as aggressive components - hydrogen sulfide and carbon dioxide. In addition, studies of corrosion inhibitors' effect on the process of preparation of production are also given. The works were carried out in the center of scientific and laboratory research of KMG Engineering branch " KazNIPImunaygas" LLP.

LEGAL FRAMEWORK AND LIABILITY OF LEAVING OIL AND GAS FACILITIES IN-SITU OR DEEP SEA DISPOSAL ON AUSTRALIA’S CONTINENTAL SHELF

2004 ◽  
Vol 44 (1) ◽  
pp. 809
Author(s):  
I.V. Stejskal
Keyword(s):  
Continental Shelf ◽  
Oil And Gas ◽  
Petroleum Industry ◽  
Legal Framework ◽  
Gas Production ◽  
Economic Life ◽  
Oil And Gas Production ◽  
Operational Life ◽  
Accepted Practice

Australia’s offshore petroleum industry is beginning to mature and many of its offshore oil and gas production facilities are reaching the end of their operational life. These facilities consist of an array of infrastructure including wells, wellheads, platforms and monopods of various construction, pipeline and flowlines, and anchors and risers. Many of these facilities will need to be decommissioned at the end of their operational and economic life in a safe and environmentally responsible manner.The Australian government has the jurisdiction to direct a company to remove all facilities associated with offshore production projects located on Australia’s continental shelf, but there is room for discretion for other decommissioning options. The manner in which facilities are decommissioned must be assessed on a case-by-case basis, taking into account factors such as technical feasibility, commercial risk, safety and social impacts, costs and environmental effects.Two decommissioning options appropriate in some instances are to leave selected facilities in-situ or dispose of a facility to some other location on the continental shelf, preferably in deep water. Residual liability refers to the responsibility and liability associated with leaving facilities on the seabed. If a facility is allowed to remain on the seabed, questions related to residual liability arise:who is responsible for any facility left on the seabed; andwho is liable to pay for compensation in the event that this facility is allowed to remain in place on the seabed and injury or damage is caused to a third person or property?There is no universally accepted practice in relation to residual liability in relation to decommissioning. In some countries, the State assumes responsibility; in other countries the company remains responsible in perpetuity. This issue still needs to be clarified in Australia.

Shaping the decommissioning landscape of tomorrow

2020 ◽  
Vol 60 (2) ◽  
pp. 537
Author(s):  
Andrew Taylor
Keyword(s):  
Service Sector ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Industry Growth ◽  
Gas Industry ◽  
Oil And Gas Production ◽  
Research Organisations ◽  
Growth Centres

Associated with the growth of Australia’s oil and gas industry over the past 40 years, our oceans currently host oil and gas production and transportation infrastructure that will cost ~AU$30 billion to decommission. National Energy Resources Australia (NERA) is one of six industry growth centres (IGC) funded by the Australian Government. NERA is investigating opportunities for transforming the way that Australia manages its upcoming decommissioning activities. In 2019, NERA undertook a series of stakeholder consultations to refresh our understanding of Australia’s decommissioning outlook. Feedback was received through more than 20 interviews and follow-up surveys with the service sector, operators, research organisations, regulators and consultants. This paper highlights the outcomes of this review and NERA’s view on opportunities to position Australia favourably to manage decommissioning in a way that maximises benefits.

Erosion of Elbows in Oil and Gas Production Systems

2012 ◽  
Vol 479-481 ◽  
pp. 1129-1132
Author(s):  
Wang Ming Bo
Keyword(s):  
Oil And Gas ◽  
Production Systems ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Gas Industry ◽  
Oil And Gas Production ◽  
Sand Erosion ◽  
The Subject ◽  
Erosion Mechanisms ◽  
Definitive Methods

This paper gives an overview of erosion mechanisms in elbows in oil and gas production systems. The nature of the erosion process itself makes it very difficult to develop some definitive methods or models to prevent or predict the erosion in elbows in all conditions. This paper provides a review of the subject which will help petroleum engineers to handle the erosion problems in oil and gas industry. This review is given of different erosion mechanisms connected with sand erosion and the factors that influence them, and then the review goes on to look at particulate erosion in elbows in more details. Conclusions are then drawn based on the above analyses.

Dropped Object Impact Analysis of Subsea Tree Frame

2014 ◽  
Author(s):  
Kumarswamy Karpanan ◽  
Craig Hamilton-Smith
Keyword(s):  
Impact Analysis ◽  
Oil And Gas ◽  
Terminal Velocity ◽  
Gas Production ◽  
Element Analysis ◽  
Oil And Gas Production ◽  
Operational Life ◽  
Critical Components ◽  
Electrical Components ◽  
The Impact

Subsea oil and gas production involves assemblies such as trees, manifolds, and pipelines that are installed on sea floor. Each of these components is exposed to severe working conditions throughout its operational life and is difficult and expensive to repair or retrieve installed. During installation and operation, a rig/platform and several supply vessels are stationed on the waterline directly above the well and installed equipment below. If any object is to be dropped overboard, it presents a hazard to the installed equipment. A subsea tree comprises of a number of critical components such as valves and hydraulic actuators, in addition to several electrical components such as the subsea control module and pressure/temperature gauges. Their ability to operate correctly is vital to the safe production of oil and gas. If an object were to impact and damage these components, resulting in their inability to operate as intended, the consequences could be severe. In this paper, a typical subsea tree frame is analyzed to ensure its ability to withstand the impact from an object accidentally dropped overboard. This was accomplished using nonlinear dynamic Finite Element Analysis (FEA). In this study, the framework was struck by a rigid body at terminal velocity, resulting in a given impact energy. Displacements and resultant strain values at critical locations were then compared to allowable limits to ensure compliance to the design requirements.

scholarly journals Advances in Asset Management Techniques: An Overview of Corrosion Mechanisms and Mitigation Strategies for Oil and Gas Pipelines

2012 ◽  
Vol 2012 ◽  
pp. 1-10 ◽  
Author(s):  
Chinedu I. Ossai
Keyword(s):  
Risk Assessment ◽  
Asset Management ◽  
Oil And Gas ◽  
Operation Time ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Mitigation Strategies ◽  
Maintenance Cost ◽  
Oil And Gas Production ◽  
Management Techniques

Effective management of assets in the oil and gas industry is vital in ensuring equipment availability, increased output, reduced maintenance cost, and minimal nonproductive time (NPT). Due to the high cost of assets used in oil and gas production, there is a need to enhance performance through good assets management techniques. This involves the minimization of NPT which accounts for about 20–30% of operation time needed from exploration to production. Corrosion contributes to about 25% of failures experienced in oil and gas production industry, while more than 50% of this failure is associated with sweet and sour corrosions in pipelines. This major risk in oil and gas production requires the understanding of the failure mechanism and procedures for assessment and control. For reduced pipeline failure and enhanced life cycle, corrosion experts should understand the mechanisms of corrosion, the risk assessment criteria, and mitigation strategies. This paper explores existing research in pipeline corrosion, in order to show the mechanisms, the risk assessment methodologies, and the framework for mitigation. The paper shows that corrosion in pipelines is combated at all stages of oil and gas production by incorporating field data information from previous fields into the new field’s development process.

scholarly journals Utah

2020 ◽  
Vol 6 (3) ◽  
Author(s):  
Mark Burghardt ◽  
Gage Hart Zobell
Keyword(s):  
Crude Oil ◽  
Oil And Gas ◽  
Oil Production ◽  
Oil And Gas Industry ◽  
Legal Framework ◽  
Gas Production ◽  
Mandatory Reporting ◽  
Gas Industry ◽  
Oil And Gas Production ◽  
Crude Oil Production

Oil and gas production continues to be an important sector of Utah’s economy. Following a 25% loss in production between 2014 and 2015, Utah’s production continues to slowly rebound. Crude oil production in 2019 appears to be slightly ahead of 2018 production. Monthly production averages slightly over three million barrels, placing Utah among the top ten states in crude oil production. Along with the continuing increase in production, the state’s legal framework governing oil and gas continues to develop. This Article examines recent changes in Utah statutes and regulations along with new case law developments involving the oil and gas industry. In particular, this Article discusses a recent federal bankruptcy decision involving midstream agreements, the revision to a Utah statute that now requires mandatory reporting of unclaimed mineral interests, and recent revisions to Utah’s oil and gas regulations.

scholarly journals Design of inductors for the installation of induction soldering of pipeline joints in the oil and gas industry

2021 ◽  
Vol 2094 (4) ◽  
pp. 042017
Author(s):  
A O Stupin ◽  
D V Rogova ◽  
E A Nozdrenko ◽  
V V Kukartsev ◽  
A I Cherepanov ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Schematic Diagram ◽  
Mathematical Apparatus ◽  
Gas Pipelines ◽  
Gas Industry ◽  
Oil And Gas Production ◽  
Induction Brazing ◽  
Oil And Gas Pipelines

Abstract The article discusses the use of induction brazing for connecting oil and gas pipelines. The rationale for the choice of induction brazing in the oil and gas industry is considered. The work calculates the main parameters of the inductor. On the basis of calculations, using a mathematical apparatus, a schematic diagram of an inductor with a diameter of 90 mm is created for installing induction soldering. It is proposed to use and develop inductors of various diameters (60, 90 and 135 mm) to create an induction unit that allows connecting pipelines of oil and gas equipment in order to increase the reliability of equipment and the efficiency of oil and gas production and processing.

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