THE COMPETITIVENESS OF THE AUSTRALIAN FISCAL REGIMES FOR OIL, GAS AND LNG COMPARED TO PRODUCTION SHARING CONTRACTS IN SOUTHEAST ASIA

2000 ◽  
Vol 40 (1) ◽  
pp. 765
Author(s):  
M.D. Sarich
Keyword(s):  
Net Present Value ◽  
Oil And Gas ◽  
Worked Examples ◽  
Cash Flows ◽  
Resource Rent ◽  
Production Sharing ◽  
Petroleum Resource ◽  
Degree Of Certainty ◽  
Fiscal Regimes ◽  
Oil Gas

With uncertain energy markets in Asia, each energy exporting country needs to be aware of the competitiveness of its fiscal regime. Oil and gas companies are quick to find fault with fiscal regimes, while governments can be slow to react to industry demands.Companies are using increasingly sophisticated methods of project selection. Therefore, if governments wish to encourage exploration and development while ensuring a fair return to the nation, they must constantly analyse fiscal terms and their impact on cash flows for the most common forms of oil and gas projects in the country.This paper takes an objective look at the competitiveness of Australia's Petroleum Resource Rent Tax and royalty/excise fiscal regimes for oil, gas and LNG projects against fiscal regimes in Indonesia, Malaysia and Papua New Guinea. Worked examples have been calculated for each regime to compare Australia's system relative to the other major producing countries in the region.Australia's onshore and offshore regimes are shown to be very competitive with respect to net present value. In addition, Petroleum Resource Rent Tax is one of the more progressive regimes in the region. However, Production Sharing Contracts in Indonesia and Malaysia are seen to be potentially more flexible when considering the varying nature of oil and gas projects, and they can provide a greater degree of certainty as the negotiated terms remain fixed for the life of contracts.

Getting the message across—taxation contribution of the petroleum industry in Australia

2015 ◽  
Vol 55 (2) ◽  
pp. 432
Author(s):  
Carlo Franchina ◽  
Rod Henderson ◽  
Praneel Nand
Keyword(s):  
Common Ground ◽  
Oil And Gas ◽  
Petroleum Industry ◽  
Oecd Country ◽  
Life Cycles ◽  
Income Taxes ◽  
Resource Rent ◽  
Petroleum Resource ◽  
The Common ◽  
Oil And Gas Companies

With the global move towards tax transparency reporting measures, resource companies face challenges in ensuring that reporting captures the full extent of revenues contributed by resource companies and also correctly reports the project and profitability life cycles of resource companies. This extended abstract focuses on the global tax transparency debate and highlights the challenges for large Australian and global oil and gas businesses in demonstrating their payment of their fair share of tax and contributing to the communities in which they operate. Issues to be covered include: A summary of the revenue contribution of oil and gas companies in Australia through the layers of taxation, such as state royalties, the Petroleum Resource Rent Tax (PRRT) and corporate income taxes. Highlighting the types and rates of taxes paid by Australian oil and gas companies compared to other selected countries. A comparison of the concessions granted to Australian oil and gas companies to other countries. A historical summary of taxes paid by Australian oil and gas companies. A summary of existing and developing transparency reporting, such as the Australian Taxation Office (ATO) reporting of taxpayers with revenues more than A$100 million, the Extractive Industries Transparency Initiative, Dodd Frank rules, OECD country-by-country reporting, and BEPS developments. Recommendations to get the message across; that is, what should be the common ground on reporting the actual overall global tax liability including income tax, resource taxes, employment taxes and indirect taxes.

Contemporary fiscal issues impacting M&A in the oil and gas sector

2012 ◽  
Vol 52 (1) ◽  
pp. 149
Author(s):  
Kenneth Wee
Keyword(s):  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Regular Feature ◽  
Gas Industry ◽  
Resource Rent ◽  
Petroleum Resource ◽  
Recent Developments ◽  
Australian Economy ◽  
To Come ◽  
Oil And Gas Sector

Ongoing growth in deal activity in the oil and gas industry is one of the critical forces underpinning the sustained robustness of the Australian economy. Australian oil and gas assets continue to attract significant international interest and are actively pursued by global and domestic investors alike. On the supply side, exploration players are seeking the necessary funding and technical support to commercialise prospective oil and gas discoveries, while on the demand side, major established oil and gas companies are seeking to acquire viable targets as a means of rapidly replenishing their reserves. Consequently, merger and acquisition (M&A) deals and asset trades have become a regular feature of the corporate oil and gas scene in Australia. In time to come, a wave of industry consolidation is likely to emerge. This paper discusses key fiscal aspects of M&A transactions, as affected by recent developments in the Australian taxation landscape, and their impact on the overall economics of, and extracting value from, an investment in the oil and gas sector, including: the taxation of farm-in/farm-out arrangements, asset swaps and carry arrangements; structuring the deal consideration for fiscal efficiency; takeover and acquisition vehicle structures; the M&A issues associated with the extension of the Petroleum Resource Rent Tax (PRRT) to the onshore oil and gas industry; consideration associated with capital management, capital structure and financing trends for the industry; exit and repatriation routes—do all roads lead to tax?; managing transaction costs; and, managing tax risks in M&A deals.

Tax issues impacting acquisitions in the Australian oil and gas industry

2011 ◽  
Vol 51 (2) ◽  
pp. 669
Author(s):  
Chad Dixon
Keyword(s):  
Income Tax ◽  
Oil And Gas ◽  
Investment Decision ◽  
Oil And Gas Industry ◽  
Capital Gains ◽  
Capital Gains Tax ◽  
Gas Industry ◽  
Resource Rent ◽  
Goods And Services ◽  
Petroleum Resource

Understanding the tax implications and structuring options of a transaction is critical when assessing and comparing new opportunities. When undertaking any transaction involving Australian oil and gas assets, the applicable taxation regime should be carefully explored and understood. From an Australian perspective, taxes such as corporate income tax, petroleum resource rent tax, capital gains tax, and goods and services tax have significant potential to influence the investment decision. This presentation will focus on the tax implications applicable to the acquisition and disposal of Australian oil and gas assets, providing valuable insights for both Australian companies and inbound investors.

Unitisation of petroleum project interests

2015 ◽  
Vol 55 (2) ◽  
pp. 497
Author(s):  
Wee Kenneth
Keyword(s):  
Oil And Gas ◽  
Development Project ◽  
Capital Gains ◽  
Capital Gains Tax ◽  
Resource Base ◽  
Resource Rent ◽  
Petroleum Resource ◽  
Key Issues ◽  
The Impact ◽  
Fiscal Implications

Traditionally, the unitisation of oil and gas project interests involved the exchange of legal ownership interests between project proponents to achieve uniformity of their licence interests across the project. Recently, more contemporary and creative forms of unitisation have emerged including economic, beneficial and contractual unitisation approaches that do not necessarily involve the transfer of legal title interests. Unitisation is a way of pooling resources to improve the likelihood of an economically viable project for participants and to overcome practical challenges resulting from uneven interests in the component parts of a broader project. In some cases, unitisation is the catalyst for project sanction. Achieving agreement and alignment on the most equitable unitisation outcome, including the valuation of the relative resource base and ownership stakes, is not easy. It involves navigating a myriad of legal, commercial, operational and financial considerations. A project residing in both federal and state waters can add increasing layers of complexity due to the interaction between overlapping federal and state jurisdictional and taxing rights. This extended abstract discusses key issues arising in various unitisation models and considers the associated fiscal implications from income tax, capital gains tax, petroleum resource rent tax and royalty perspectives. It also examines the government’s announced tax measures for dealing with the swapping of interests or interest realignments resulting in a common development project and the impact and effectiveness of these rules on unitisation arrangements.

The petroleum resource rent tax (PRRT) and the economics of an oil and gas project

2014 ◽  
Vol 54 (2) ◽  
pp. 515
Author(s):  
Carlo Franchina ◽  
Ben Opie
Keyword(s):  
Oil And Gas ◽  
Due Diligence ◽  
Critical Importance ◽  
Resource Rent ◽  
Contract Negotiation ◽  
Petroleum Resource ◽  
Key Drivers

When thinking about the key drivers of project value, the PRRT profile of a petroleum project may not be top of mind for non-tax teams. As a 40% tax on the upstream activities of a petroleum project, however, the PRRT can significantly impact on project NPV and non-tax teams can play an important role in optimising the PRRT profile of a project. For finance and legal teams, this may be as part of the due diligence, modelling, and contract negotiation phase of acquiring or disposing of an interest in a project. Operational and technical teams can play an important role in helping tax teams to understand a project so that they can apply tax technical concepts; for example, in determining the characterisation of expenditure. Properly substantiating PRRT expenditure is also of critical importance; finance, IT, commercial, and operational teams should be involved in developing systems that capture the information tax teams require to be able to quantify and evidence PRRT deductions. This extended abstract focuses on the practical ways in which non-tax teams can help optimise the PRRT profile and, in turn, the NPV of a petroleum project.

scholarly journals Efficiency Assessment of Economic International Cooperation in Development of Arctic Offshore Oil and Gas Resources

2015 ◽  
pp. 128-136
Author(s):  
P. V. Beresneva
Keyword(s):  
Public Policy ◽  
International Cooperation ◽  
Net Present Value ◽  
Oil And Gas ◽  
Technology Development ◽  
Cash Flows ◽  
Oil And Gas Resources ◽  
Offshore Oil And Gas ◽  
Definition Of ◽  
Offshore Oil

The research is focused on efficiency assessment of economic cooperation in development of Arctic offshore oil and gas resources. The author developed an economic model based on cost-benefit analysis (CBA). CBA is used in some countries (EU, USA, Australia) as an analytic tool to make public policy decisions. CBA is based on the method of discounting cash flows associated with costs and benefits of public policy. It is assumed that all public goals are equally important inter alia, hence public bodies should opt for those initiatives that maximize public benefits for every dollar spent from the state budget. There are five stages of economic modeling: 1) the definition of public benefits and costs associated with the public initiative; 2) monetary valuation of costs and benefits; 3) the definition of discounting period and discounting rate; 4) the calculation of net present value of cash flows; 5) the comparison of initiatives' net present values. The model is built with a number of hypotheses assumed. It allows making evaluation of investments into the technology to decrease the cost of Arctic offshore oil and gas development. Moreover, the model has two scenarios describing a public policy to support technology development with international economic cooperation and without it. Under given hypotheses both scenarios return positive net present value of policies which proves that governmental initiative to support Arctic technology development is economically justified. Also the model sows that the scenario with international cooperation is more efficient from economic point of view. It is explained by two factors: the higher speed of technology transfer (due W international cooperation) and the opportunity to use financial leverage (attracting the funds from foreign partners). The model allows closing the existing scientific gap between the theory of CBA method and its practical use in public decision making.

scholarly journals OIL & GAS INDUSTRY IN BRAZIL: A BRIEF HISTORY AND LEGAL FRAMEWORK

2018 ◽  
Vol 1 (1) ◽  
pp. 223-252
Author(s):  
Laís Palazzo Almada ◽  
Virgínia Parente
Keyword(s):  
Large Scale ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Legal Framework ◽  
Energy Sources ◽  
Gas Industry ◽  
Production Sharing ◽  
Salt Layer ◽  
Gas Market ◽  
Oil Gas

The recently announced discovery of potential large-scale reserves in the Brazilian so called pre-salt layer has resulted in a new legal framework for the country. In this new architecture, old and new regulation share the legal arena. Exploring this context, this paper provides an overview of the emergence and evolution of the oil and gas market in Brazil, and discusses the new legal configuration where the prevailing Concession System co-exists with the Production Sharing System and the Onerous Assignment. The conclusion pinpoints the challenges that the country faces in dealing with two energy sources –oil and gas— that will play an increasing role in Brazil’s future. It also indicates that the introduction of competition also has brought new features and improvements to oil and gas industry in Brazil. Structuring a robust legal framework that will foster the necessary investments is not only a challenge for the Brazilian economy, but also one that has to be tackled by many emergent economies with newly hydrocarbon discoveries.

scholarly journals OIL & GAS INDUSTRY IN BRAZIL: A BRIEF HISTORY AND LEGAL FRAMEWORK

2018 ◽  
Vol 1 (1) ◽  
pp. 223-252
Author(s):  
Laís Palazzo Almada ◽  
Virgínia Parente
Keyword(s):  
Large Scale ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Legal Framework ◽  
Energy Sources ◽  
Gas Industry ◽  
Production Sharing ◽  
Salt Layer ◽  
Gas Market ◽  
Oil Gas

The recently announced discovery of potential large-scale reserves in the Brazilian so called pre-salt layer has resulted in a new legal framework for the country. In this new architecture, old and new regulation share the legal arena. Exploring this context, this paper provides an overview of the emergence and evolution of the oil and gas market in Brazil, and discusses the new legal configuration where the prevailing Concession System co-exists with the Production Sharing System and the Onerous Assignment. The conclusion pinpoints the challenges that the country faces in dealing with two energy sources –oil and gas— that will play an increasing role in Brazil’s future. It also indicates that the introduction of competition also has brought new features and improvements to oil and gas industry in Brazil. Structuring a robust legal framework that will foster the necessary investments is not only a challenge for the Brazilian economy, but also one that has to be tackled by many emergent economies with newly hydrocarbon discoveries.

FISCAL Optimizations to Achieve a Win-Win Gross Split Production Sharing Contract on Deep-Water Study Case Project

2021 ◽  
Author(s):  
A. H. Sasoni
Keyword(s):  
Net Present Value ◽  
Oil And Gas ◽  
Economic Modelling ◽  
Effective Tax Rate ◽  
Tax Rate ◽  
Field Development ◽  
Production Sharing ◽  
Cumulative Production ◽  
The Government ◽  
One Year

Indonesia has adopted a new oil and gas fiscal system called Gross Split PSC (Production Sharing Contract). The objective is to implement a better system for developing oil and gas projects in Indonesia, which will empower the government to secure a higher government take (GT) from the early stages of production and reduce bureaucracy for contractors. This individual project compares the new PSC scheme and the Traditional PSC system using deterministic sensitivity analysis to determine the most optimal fiscal terms under the Gross Split PSC. The discussion includes profitability index, such as the government’s share of gross revenue (GSGR), project’s net present value (NPV) and the internal rate of return (IRR). The work was carried out from both the contractor’s and government’s perspective in an Indonesian Petroleum Association (IPA) simulation gas case study field development in deep offshore. The results of the economic modelling analysis provides that Gross Split PSC will have the same IRR as the Traditional PSC if the project is accelerated for one year, receives a 5% deductible effective tax rate and gets an additional progressive split of cumulative production.

scholarly journals The Problem of Determining Discount Rate for Integrated Investment Projects in the Oil and Gas Industry

Mathematics ◽  
2021 ◽  
Vol 9 (24) ◽  
pp. 3327
Author(s):  
Alexey Komzolov ◽  
Tatiana Kirichenko ◽  
Olga Kirichenko ◽  
Yulia Nazarova ◽  
Natalya Shcherbakova
Keyword(s):  
Discount Rate ◽  
Net Present Value ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Cash Flows ◽  
Practical Implementation ◽  
Gas Industry ◽  
Investment Projects ◽  
Integrated Project ◽  
Methodological Approaches

The main aim of this paper was to examine specific approaches to determining the discount rate for comprehensive computation of investment projects efficiency in the oil and gas industry. The objective of the study was to develop a scientific approach for determining the discount rate for integrated oil and gas projects. The authors analyze dynamic methods for determining the efficiency of investment projects in the oil and gas industry and conclude that they are advisable for oil and gas projects due to the high capital intensity of the projects and their long payback period. Regarding the need to implement dynamic indicators of efficiency, the authors set the task of deter-mining the proper discount rate as a factor having a significant impact on effectiveness evaluation. The discount rate is proposed to be evaluated by solving the equation and finding the break-even point where the NPV (net present value) of the integrated project will be equal to 0 (taking into account the revenue of the subprojects included in the complex). The practical implementation of methodological approaches to assessing the discount rate for integrated projects is relevant due to the execution of large, systemically important and integrated projects. As a result of the study, the authors put forward a methodological algorithm for determining the discount rate of an integrated project which assumes an assessment of cash flows for the subprojects included in the complex; determination of the target rate of return for subprojects; and calculation of prices for products at which a complex project become break-even. The practical implementation of methodological approaches to assessing the discount rate for integrated projects is relevant due to the execution of large systemically important integrated projects.

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