Gas Assets Research Articles

Integrating Analytic Hierarchy Process in Assessing the Criticality of Vulnerable Oil and Gas Infrastructure to Climate Change Impacts in the Niger Delta

The Niger Delta is under severe threat from the impacts of climate change in the form of flood, rising temperature, surging Atlantic tides, persistent heavy rainfall, and windstorms. The severity of the impacts on current and planned oil/gas infrastructures calls for urgent adaptation strategies. To adapt effectively, prioritisation of oil and gas infrastructures according to their criticality is crucial. This paper applied a systematic review of highly referenced journal articles published between 2008 and 2019 to scope and synthesise specific criticality assessment criteria for evaluation. Analytic hierarchy process (AHP) was implemented in criteria-based pairwise comparison and prioritisation of selected infrastructures. Practitioners with at least ten years of experience in the oil/gas industry in the Niger Delta were stratified accordingly for data collection through a perception-based pairwise comparison technique. The result was analysed using Mi-AHP software and shows the global priorities (eigenvector, EV) for each asset. Terminals, flow stations and roads/bridges obtained the highest EV = 0.27, 0.19, and 0.15 respectively; indicating their high criticality level in the oil and gas assets value chain. The result also shows that transformers/high voltage cable are the fourth most critical systems obtaining EV = 0.14 while Pipelines, loading bays and wellheads were ranked fifth, sixth, and seventh with EV = 0.11, 0.09 and 0.05. The paper portrays AHP as an effective tool in decomposing complex decision-making processes for evaluation of critical infrastructures for climate adaptation planning in the oil and gas industry.

The Long Road To First Oil

This paper analyzes the factors affecting the speed at which newly discovered oil and gas fields are developed. Using data from over 25,000 oil and gas assets globally I demonstrate that both asset and country characteristics are critical in determining which assets reach production stage. I analyze the effects of countries adopting a set of market oriented reforms, to shed light on the impacts of institutional changes on petroleum extraction timeline. Mitigating climate change will require a large share of the world's already discovered fossil resources to stay underground. The results of this study can help inform how petroleum producers may respond to the energy transition underway. My findings also calls into question the assumption used in earlier research that giant oil and gas discoveries can be considered exogenous in their impacts on subsequent production.

Data-Driven Analytics Provide Novel Approach to Performance Diagnosis

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 192759, “Data-Driven Analytics: A Novel Approach to Performance Diagnosis Using Spatiotemporal Analysis in a Giant Field Offshore Abu Dhabi,” by Mohamed Mehdi El Faidouzi, SPE, and Djamel Eddine Ouzzane, ADNOC, prepared for the 2018 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, 12–15 November. The paper has not been peer reviewed. This work describes a heuristic approach combining mathematical modeling and associated data-driven work flows for estimating reservoir-pressure surfaces through space and time using measured data. This procedure has been implemented successfully in a giant offshore field with a complex history of active pressure management with water and gas. This practical work flow generates present-day pressure maps that can be used directly in reservoir management by locating poorly supported areas and planning for mitigation activities. Field Overview The giant oil field offshore Abu Dhabi covers an area of approximately 40×25•km. The structure is a low-relief anticline. The fault pattern is dominated by steep northwest/southeast strikes, with less-abundant northeast/southwest strikes. The fault throws are generally small, and most faults are unlikely to be sealing laterally. The oil accumulation is separated by dense argillaceous limestones into three distinct, stacked reservoirs (A, B, and C), each approximately 20 to 35 ft thick. Formation-pressure tests showed good intrareservoir vertical pressure communication. Occasionally, especially toward the north and east, a generally tight clay-prone lithology forms a localized barrier between the upper and basal layers of Reservoirs A and B. The complete paper examines the case of the upper layers of Reservoir A in particular, a laterally extensive porous carbonate deposited in a shallow-water environment, although the work flows developed are equally applicable to other reservoir zones. Commercial production of Reservoir A began in the late 1960s. After an initial period of natural depletion, various pressure-maintenance strategies were deployed, namely dump-flood (1972–1984), peripheral water injection (from 1979), and crestal gas injection (from 2005). Spatiotemporal Analysis of Pressure Data Prediction of spatial random fields is a common task in geostatistics and arises in geology, mining, hydrology, and atmospheric sciences. Kriging procedures are used routinely to make optimal predictions at unsampled locations. For quantities that vary in space and time, such as reservoir pressure, spatiotemporal interpolation can provide more-accurate predictions than purely spatial interpolation because observations at other times are considered. In producing oil and gas assets, reservoir-pressure measurements are made at a much higher frequency in the time domain compared with the spatial domain, which requires additional wells to be drilled. The conventional approach of using a spatial interpolation on the basis of a certain time period misses valuable information and could result in inconsistencies between maps from one time period to the next. In this case study, the authors present a heuristic approach to estimating reservoir pressure maps in Reservoir A on the basis of spatiotemporal interpolation. Reservoir pressure is modeled using smooth functions that capture global trends while preserving the spatial and temporal continuity of pressure and pressure gradient. The residuals can be described by a stationary and spatially isotropic process. Residuals then can be predicted at unsampled space and time locations by kriging.

Physics-guided neural networks for predicting unconventional well performance — using Unconventional Rate Transient Analysis for smarter production data analytics

Geoscience modelling poses many challenges due to the limited sampling and the complexity of the phenomena that create the resulting rock and its properties. When adding to the geologic and geomechanical complexity the various possible fluid flow mechanisms that are often not fully understood, one realizes quickly how daunting geomodelling could be. As a result, oil and gas fields are often bought and sold using reserves computed with simple decline curve analysis tools. Unfortunately, these simplified production analysis tools contain no physics and do not help develop oil and gas assets which require the knowledge of 1) rock properties distribution and 2) the impact of the rock properties on the selected production mechanism. For example, if one has a naturally fractured reservoir, the presence or absence of the natural fractures and the way the wells are drilled to encounter or avoid these rock properties will determine the reserves and the future of the company developing such an asset. Very often the future of many companies is not very bright due to their lack of knowledge of the distribution of the rock properties such as natural fractures and the subsequent fluid flow resulting from drilling and fracking into these heterogeneous rock properties. For the companies that want to prosper by intelligently developing their assets, niche companies and technologies have been used throughout the years to address all these challenges. Among these technologies we find the use of artificial intelligence and machine learning, which were introduced in the oil and gas industry in the early 1990s with successful application to petrophysics, well test analysis and reservoir modelling. Three decades later, the oil industry and its unconventional revolution is facing frequent challenges ranging from frac hits and well interferences, casing deformation and collapses, expensive cube development with meagre returns on investment and many other puzzling issues with no easy solution. Suddenly, under the stress of financial constraints, the machine learning tools criticized for three decades as ‘black boxes’ are now becoming the preferred solution to all problems. Unfortunately, this love-hate relationship the oil industry has with data-driven approaches may hit a rough patch very soon due to its inability to recognize the limitations of the available data used in the various oil and gas challenges.

Developing global champions: Why national oil companies expand abroad

AbstractNational oil companies (NOCs) have invested hundreds of billions of dollars in foreign oil and gas assets. Why have some governments increased their NOC outward investments, while others have not? I argue that domestic structures can influence a government's calculus that potential benefits, such as added revenues and fuel supply, outweigh potential costs, such as information asymmetries and inefficiencies associated with NOCs. Nationally, partisan competition limits democratic tolerance for failures by NOCs. Bureaucratically, overlapping authority in energy policy undermines coherent NOC governance. Based on investments by NOCs hailing from 79 countries, 2000–2013, I find robust evidence for the national hypothesis.

Valuation of upstream oil and gas assets

This article addresses the valuation of upstream oil and gas assets – hydrocarbon reserves and resources - within a conceptual framework intended to be clear to non-technically-trained or experienced readers. The first part of the article addresses in detail the mechanics of quantifying the underlying hydrocarbon volumes, translating these into (the expectation of) future cash flows which underpin value, and the incorporation of risk. The second part of the article focuses in more detail on utilizing the cash flow analysis to create a valuation opinion, and validating that opinion using other market metrics (which can also be used on occasions where the data required for a cash flow analysis is not available). It also comments upon a number of issues and considerations that come into play and may underlie the differences or be the cause of contention between parties who assert very different opinions of value. The whole valuation process requires bringing together a large number of considerations, many of which are subject to considerable uncertainty. Care must therefore be taken not to imply an accuracy in the opinion concluded which, in reality, will almost certainly have a reasonable range of uncertainty that sometimes can be quite wide.

Unpacking EU external energy governance vis-a-vis Egypt: contradictions, geopolitics and Euro-centrism

ABSTRACT Energy diplomacy, regulation of the single energy market and the export of this regulatory model to EU’s vicinity govern EU energy affairs. This governance nexus, however, suffers from three distinct shortcomings. This paper addresses these in the context of EU external energy governance vis-à-vis Egypt. Firstly, it highlights how geopolitical rationales blur the commercial logic in pipeline politics, derail gas schemes, and marginalize Egypt despite its pivotal energy role. Secondly, it showcases how the three governance modes contradict each other and add layers of contingencies in EU-Egypt gas trade. Thirdly, it questions EU’s hierarchal approach to Egypt, demonstrating how the EU suffers from a clear misconception of Egypt’s role and interests, and hence fails to tap into Egypt’s gas assets.

Orphaned wells, oil assets, and debt: the competing ethics of value creation and care within petrocapitalist projects of return

AbstractThis essay explores the phenomenon known as ‘orphaned wells’, meaning unprofitable oil and gas wells (‘legacy wells’) that have become disentangled from their corporate owners owing to insolvency, or owing to a failure to comply with local regulations. Drawing from an ethnographic example of a near‐insolvent oil and gas corporation in Alberta, Canada, and its strategies of refinancing, the essay explores how value creation and the moral force of the obligation to create a financial return give rise to a ‘durational ethics’ that shapes corporate and financial performativities and prolongs the ‘life’ of legacy oil and gas assets. Legacy assets, understood as potential orphans, are thus caught up in a lively corporate practice of asset circulation and recombination often deployed by producers for the moral work of ‘cleaning balance sheets’. This essay calls for ‘thinking with orphans’ to recognize the competing ethical registers which produce them in addition to the growing need for responsibility and corporate care for legacy oil and gas assets.

KEY ISSUES OF ACCOUNTING FIXED ASSETS MANAGEMENT OF OIL AND GAS ENTERPRISES: ANALYSIS OF FEATURES, COMPOSITION AND VALUATION

The article deals with the key issues concerning the system of security of fixed assets at the enterprises of the oil and gas industry. The purpose of the article is to investigate the fixed assets features and composition at the the enterprises of oil and gas industry, to determine the approaches to their assessment at the stage of their receipt by the enterprise. The state, dynamics of value and the degree of depreciation of fixed assets in Ukraine for the year 2017 have been analyzed, their features have been distinguished at the enterprises of different branches of the economy. To ensure the effective operation of the enterprises of the oil and gas industry, significant assets are required, and the results of their activities to a large extent depend on the availability and condition of fixed assets that ensure economic sustainability of economic entities. Oil and gas companies include pipelines and related equipment in fixed assets, oil and gas assets, machinery and equipment, buildings, buffer gas, drilling and reconnaissance equipment and other fixed assets. Among the assets of NJSC "NAFTOGAZ OF UKRAINE" for the year 2017, non-current assets occupied 86% of the total assets of the company, of which 94% were fixed assets, what determines the reliability of their accounting as an important element of effective management of enterprises. The dynamics of value and composition of fixed assets of enterprises of the oil and gas industry of Ukraine for 2016-2017 have been determined according to separate economic segments. The cost of fixed assets of NJSC "NAFTOGAZ OF UKRAINE" as of December 31, 2017 amounted to UAH 491 482 million, respectively, according to economic segments, it is structured in such a way that their largest share is concentrated in the system of transportation and distribution of natural gas - almost 48%, for storage of natural gas - 34%, production and sale of natural gas - 12%, and the rest belongs to the economic activities related to oil: the production of crude oil and gas condensate, transportation of crude oil. The composition of fixed assets of extractive enterprises differs from their composition in refineries. Industrial features of mining industry with significant volumes of work related to the disclosure of layers of minerals are characteristic to chemical production with a significant cost of equipment. The main approaches to the evaluation of fixed assets objects at the stage of their entrance to the enterprise have been investigated. The reliability of the accounting information on fixed assets depends on their assessment. When they are received, they are valued at their original cost, that is, by the amount of cash paid or their equivalents or fair value, another form of indemnity granted to obtain the asset at the time of its acquisition or creation, or, if accepted, the amount that is distributed to that asset in the original recognized in accordance with the specific requirements of other IFRSs. After recognition, the entity should choose either a cost model or a revaluation model in its accounting policies and should apply this policy to the entire group of fixed assets. A cessation of recognition occurs after the release of an object or when it does not expect future economic benefits from its use or disposal. In this case, it is recognized as profit or loss.

Net reserves evaluation and sensitivity analysis of shale gas project under royalty & tax system in British Columbia, Canada

With the declination of production and increasing of fossil-fuel demand, petroleum companies strive to maximize production by conducting more advanced drilling operations, such as extended reach, horizontal and high-pressure/high-temperature (HP-HT) drilling and multi-stage hydraulic fracturing, which are expanding globally into unconventional resources drilling. Shale gas, which constitutes for a significant percentage of the natural gas resource base and offers tremendous potential for future reserve and production growth, was becoming the increasingly important asset for petroleum companies. This paper took a shale gas project in British Columbia (Canada) as an example, combining the characteristics of the shale gas reservoirs with royalty & tax policy of this region. The research on shale gas reserve evaluation and the principles of net reserve calculation under royalty & tax contract was carried out. The four main aspects such as technique, economy, commerce and engineering, were studied to analyze the influence on net reserves from the following factors: production, declining rate, development plan, oil price, Opex(operating costs), Capex(investment) and taxes, etc. Sensibility analysis was conducted by adopting the most weighted factors, such as oil prices, production, Opex and Capex. All the effort was to put forward the corresponding suggestions on optimizing development strategy, solve the current reserves evaluation problems of shale gas, and provide reference for the shale gas assets transaction, development and perfection of reserves value evaluation.

Управление нефтегазовыми активами в эпоху технологий хранения и обработки больших массивов данных

Управление нефтегазовыми активами в эпоху технологий хранения и обработки больших массивов данных

Alberta’s Oil Sands: An Unsecured Asset? An Analysis of the Mine Financial Security Program in Relation to Surface Mining of the Alberta Oil Sands

This article conducts a comprehensive review of Alberta’s Mine Financial Security Program (MFSP), the provincial program that governs the collection of financial assurance for reclamation liabilities (also known as “reclamation liability security,” “financial reclamation sureties,” or “closure bonds”). This article assesses the MFSP program in relation to surface oil sands mining. It concludes that while the recently implemented MFSP has improved some aspects of the oil sands reclamation security regime, Alberta’s MFSP still suffers from issues of transparency, inadequate collection of financial security, and utilization of underinclusive classifications of environmental liabilities. Moreover, this article analyzes the particular risk that oil sands assets have of “stranding” (namely, being unanticipatedly or prematurely written off, downwardly revalued, or converted to a liability) as well as how stranding would impact Alberta’s financial assurance regime.This article concludes that while the oil sands are at a heightened risk for asset stranding compared to the international oil industry as a whole, international oil and gas assets are unlikely to become completely stranded. This article also finds that investors have likely already priced the risk of asset stranding at 1.5–2 percent and will be unlikely to readjust their portfolios unless divestment campaigns strengthen or environmental legislation becomes more certain. The MFSP uses a method that does not account for large fluctuations in oil prices, nor does it sufficiently account for the risk of partial stranding. If asset stranding were to occur, the only way the Alberta government would be able to afford the costs of reclamation would be to paradoxically develop the very resource that was defaulted on, against the environmental legislation or political pressures that caused the stranding.

Commercial fisheries losses arising from interactions with offshore pipelines and other oil and gas infrastructure and activities

Abstract Interactions between fishing vessels and oil and gas infrastructure can result in damage to fishing gear, loss of fishing time/access, and risks to crew health and safety. The spatial and temporal patterns characterizing previous incidents (and subsequent losses) between fishers and oil and gas infrastructure were quantified and used to identify key risk factors associated with fisheries losses. Between the years 1989 and 2016, 1590 incidents that resulted in a financial loss, vessel abandonment, or an injury/fatality for UK commercial fishers were recorded. The annual number of recorded incidents decreased by 98.6% over a 27-year period. The majority of past incidences resulted in financial losses (rather than injuries or fatalities) and were associated with interactions between single otter trawlers and oil and gas production-related debris. The odds of an incidence occurring varied according to substrate type and fishing intensity. A risk-model for pipeline–fishing interactions in the Fladen Ground showed that there was significant spatial heterogeneity in the risk of an incident along a pipeline according to the angle and intensity of fishing. The results highlight the need to include the full spectrum of potential losses in fisheries impact assessments associated with the installation and decommissioning of oil and gas assets.

Risk transmission between natural gas market and stock markets: portfolio and hedging strategy analysis

This paper investigates the risk transmission and hedging strategies between natural gas market and stock markets. We propose a multivariate GARCH framework which combines regime switching with multivariate long memory and asymmetry GARCH. Results show that there exists granger causality from natural gas market to the Chinese stock markets in crisis regime. Dynamic correlations between these markets are vulnerable to extreme weather, government policies and financial crisis. When looking at the optimal design of a natural gas-stock portfolio, we find that investors in stock markets should have more stocks than natural gas asset in order to reduce their portfolio risk.

Air Liquide sues Carlyle

Air Liquide has filed a lawsuit alleging that the Carlyle Group, a private equity firm, hired a senior Air Liquide executive as part of a scheme to get its hands on confidential business information. That information could give Carlyle the upper hand in acquiring Praxair and Linde industrial gas assets being auctioned as part of the $70 billion merger of the two gases giants, announced in December 2016. Japanese industrial gas maker Taiyo Nippon Sanso agreed on July 5 to buy Praxair’s European gas business for nearly $6 billion. Taiyo, which is not now active in Europe, would get a business with annual sales of $1.5 billion, 2,500 employees, and operations in 12 countries. Carlyle and other suitors are still in the running for U.S. gas assets. Both sales are intended to quell antitrust concerns. The deal with Taiyo brings Praxair and Linde a step closer to tying the knot

Development of Competitive Environment in the Oil Market of Russian Federation: Empirical Analysis

The purpose of this research is the assessment of the competitive environment in the Russian oil market. The subject-matter of the study is the Russian oil and gas companies as a basis of the Energy market. We check the hypothesis about the development of the mechanism of corrective condition in the sphere of preliminary control of market concentrations in the fuel and energy complex (FEC). The basis of this research is the modern theory of industry markets studying various structures of the markets, the behavior of their participants, probable consequences of their functioning and interaction, as well as the impact of the state on the functioning of markets, its participants, and the results of their activities. We calculated and analyzed the key indicators characterizing the processes of market concentration in the oil industry. We also considered the competition policy of the Russian Federation in mergers and acquisitions deals (M&A deals) concerning oil and gas assets. The authors estimated over 460 decisions made by the Federal Antimonopoly Service of the Russian Federation for the period from 2011 to 2015 in the control on economic concentration in fuel-and-energy industry. Based on the data characterizing the development of competitive environment, we have proved that the considered goods market belongs to markets with insufficiently developed competition. The results of the research will make a certain contribution to studying the efficiency of M&A transactions in the oil and gas industry, and also can be applied for the implementation of anti-monopoly actions by the Federal Antimonopoly Service of the Russian Federation.

Carbon pricing with an output subsidy under imperfect competition: The case of Alberta's restructured electricity market

In this paper, we examine the use of carbon pricing and an output-based subsidy in a market with imperfect competition. We consider a carbon pricing policy in Alberta's electricity market as a case study. This policy consists of two phases. In the first phase, the carbon price is increased with the output subsidy being based on a fraction of facility-level emission intensity. In the second phase, the output subsidy is altered to be uniform across assets and based on the emissions intensity of an efficient natural gas asset. Using a model of oligopoly competition, we simulate the short-run impacts of the two phases on electricity prices, emissions, and unit and firm-level profitability. We find that the mechanisms by which electricity prices and emissions change in response to carbon pricing differ depending on whether the market is perfectly competitive or oligopolistic. We demonstrate that by differentiating the effective carbon price across technologies, changing the basis of the output subsidy has substantially larger price and emissions effects than increasing the carbon price for all generators. The estimated effects of carbon pricing vary as the firms’ generation portfolios change.

Guest Editorial: Can Additive Manufacturing Breathe New Life Into Aging Assets?

Guest editorial Additive layer manufacturing technology has gained prominence in the aerospace sector and is being used for the rapid production of prototype parts. Its credibility has quite literally “taken off” and is now used to build in-flight production components for aircraft. Its applications are being adopted in other sectors such as medical and automotive as a potentially faster and more economical alternative to traditional manufacturing methods for certain applications. Though it offers huge potential to the oil and gas arena, its uptake so far has been limited. The industry’s risk-averse culture, lack of infrastructure, and stringent standards have been cited by leaders as barriers to adoption. Yet, as experienced in other industries, the technical and economic benefits far outweigh the obstacles. The oil and gas industry’s growing focus on operational efficiency in today’s low-price climate is slowly driving change and a realization that the challenges are not insurmountable. Two main groups of technologies can be of benefit to the oil and gas industry: powder bed fusion and direct energy deposition. Both use a diverse range of metals in wire and powder form, which can be fused together using lasers, electron beams, and electric arcs. Asset Life Extension For aging oil and gas assets, replacement components may be difficult to source, require a long lead time to manufacture, and incur significant expense to produce. But the direct energy deposition additive technique called laser metal deposition could be the answer to remanufacture difficult-to-weld oil and gas components, such as those made of corrosion-resistant steels and heat-resistant super alloys. Currently, no remanufacturing procedures exist for some high-value components, but by applying additive material to a specific area that is worn, you can extend the life of a component and actually increase its functional performance. This could play a key role in enabling oil and gas opera-tors to reinstate their existing old equipment, reduce lead time, allow options to extend maintenance schedule cycles, and increase functional performance. Laser metal deposition is a powder additive manufacturing process in which powders are conveyed through a nozzle and a laser is used to melt the layer of powder into a desired shape. This process offers many benefits for the oil and gas sector and, in particular, for remanufacturing applications. It has very fast cooling rates that create a very fine microstructure. There is also very low dilution and heat-affected zone into the substrate material, meaning that thinner clad layers can be applied while still ensuring that the clad composition is achieved. A secondary benefit to lower dilution and a small heat-affected zone is that there will be shallower residual stress profiles, meaning very little distortion of components. This process can be applied very accurately, and fine features can be achieved with minimal post-process machining. Alloy powders can also be mixed together to create new alloys that can be functionally graded to obtain tailored properties.

Technology Focus: Decommissioning and Abandonment (January 2018)

Technology Focus So you don’t want to do decommissioning; just get over it. Decommissioning is a part of the life cycle of any oil and gas asset. Publicly traded firms account for these future liabilities on their books through the requirements of Financial Accounting Standard 143 from the Financial Accounting Standards Board and International Accounting Standard 37 from the International Accounting Standards Board. These costs have been considered and accounted for in the development economics for every project. Delaying decommissioning through life extensions or divestiture is laudable; but, ultimately, decommissioning will need to occur. As discussed last year, early planning for decommissioning, along with an integrated late-life/decommissioning strategy, can deliver value. The supply chain is now actively working to develop low-cost solutions and is gaining valuable experience through recent projects (as documented in many recent SPE papers). Owners need to engage the supply chain early with the relevant asset data for planning and execution of decommissioning. Don’t tell them how you want it done. Owners need enough internal expertise to be informed buyers and to select the optimal market-driven solutions offered by the supply chain. Owners then must step back and let the supply chain deliver. Another value opportunity lost appears to be decommissioning during the down cycle. Minimum costs and maximum supply-chain engagement occur during the periodic down cycles; plan to take advantage of these guaranteed cost-saving opportunities. Decommissioning—just get on with it, using the right integrated late-life/decommissioning strategy delivered during a down cycle. Recommended additional reading at OnePetro: www.onepetro.org. IPTC 18982 Net-Environmental-Benefit-Analysis Application for Jacket-Decommissioning Techniques by J. Kanmkamnerd, PTTEP, et al. OTC 27672 Baseline for Planning and Cost Estimation of Brazilian Decommissioning by F. Mimmi, Genesis, et al. SPE 186133 Brent Charlie Ultralate Life: Managing for Optimal Decommissioning by F. Sanwoolu, Shell, et al.

Smart upstream to LNG

With today’s current technologies, it is possible to answer the question, ‘What is the most profitable mode of operation for the next few hours, for the rest of today, tomorrow and beyond?’ With ‘lower for longer’ oil prices, the need for enterprise wide optimisation in the upstream and midstream oil and gas industry is greater than ever. The terms ‘Digital Oil Field’, ‘Digital Gas Field’, ‘Digital Twin’ are being utilised to extol the virtue and value of big data analytics and model-based asset optimisation and supply chain optimisation by enabling this in efficient ways not previously possible with multiple unintegrated systems, processes and procedures. Multiple different point solutions rolled out across multiple sites become difficult to integrate horizontally for management of safe and optimised operations and vertically up to business enterprise resource planning level to give useful and timely business insights. With careful planning, coupled with deep operational technology and operations knowledge, an integrated enterprise wide supply chain and asset operations and management system can unlock significant hidden value. This is enabled by the correct and efficient integration of many systems and the efficient collection, management and use of huge amounts of data. As the industry needs to ‘do more with less’, getting this integration right is critical to enable desired outcomes and functionality. This paper summarises the current state-of-the-art solutions that enable optimised well to liquefied natural gas plant process, asset and business management to deliver desired functionality and outcomes.