Domestic Gas Supply Research Articles

The rising significance of the Perth Basin

Amid a nationwide struggle to revitalise exploration and development activity in the Australian oil and gas industry, the Perth Basin emerges as a beacon of hope. During 2003–2005, the basin experienced a peak in exploration activity, averaging an impressive 13 wells drilled per year. However, mirroring the sector’s broader nationwide trend, the Perth Basin then saw a decline in drilling, with an annual average of just three exploration wells over 2006–2022. Nevertheless, a turnaround is in progress, with the basin poised for the drilling of eight exploration and appraisal wells in 2024. The turning point for the basin can be traced back to the Waitsia discovery in 2014 which rekindled interest and activity in the region, resulting in nine distinct gas discoveries and a subsequent doubling of the basin’s estimated gas resources. Against the backdrop of projected gas shortfalls in Western Australia’s domestic market, players in the basin have ambitious development plans amid rising gas prices. We expect that the Perth Basin could contribute up to 30% of WA’s domestic gas supplies by 2030, compared to a modest 5% in 2023. Notably, a substantial portion of WA’s new gas supplies are expected to originate from the Perth Basin. This paper examines the resurgence of activity and interest in the Perth Basin, driven by surging valuations and its growing significance within the domestic gas market. It also examines the commercialisation pathways in light of the updated ban on onshore gas exports in WA.

The impact of exploration/appraisal activities on the recovery per well in North Perth Basin

The North Perth Basin (NPB) in Western Australia has experienced significant petroleum industry activity over the past 3 years (2021–2023), marked by the drilling of exploration and appraisal wells by various operators, along with notable merger and acquisition transactions. This flurry of drilling activity, coupled with the acquisition of new seismic data, have enhanced our understanding of the variability within the primary petroleum play levels – namely, the Permian ‘Kingia’ and High Cliff reservoirs. This understanding is crucial for assessing the future potential of domestic gas supply in Western Australia. This paper aims to elucidate how recent drilling efforts have narrowed the basin-wide portfolio of available gas prospects relative to the situation in early 2021, and how the landscape of undiscovered gas resources has evolved. This shift is attributed to both unsuccessful exploration attempts and revised estimates of well deliverability. Furthermore, an updated long-term production forecast for the NPB – considering existing gas pools and the newly assessed undiscovered resources – emphasises the urgent need to re-evaluate the narrative concerning gas availability for the domestic market. The Permian gas plays within the NPB have proven to be more intricate and unpredictable than previously believed. Nonetheless, their significance to the Western Australian economy is anticipated to be substantial for many years ahead.

Implications of Western Australia’s updated domestic gas policy

In August 2023, Western Australia (WA) updated its domestic gas reservation policy to restrict onshore gas exports through the existing pipeline network, primarily affecting the Perth Basin. While the policy update aimed to secure domestic gas supplies amid projected shortfalls, it may complicate the outlook for the WA gas market through restricted access to capital, reduced incentives for substantial investments in large-scale developments, and the elimination of a potential future gas demand source for the state. WA’s domestic gas consumption is expected to peak by the end of this decade and then steadily decline as part of the state’s net-zero emission ambitions. In contrast, the liquefied natural gas (LNG) market especially in Australia’s main buying partners in Asia is set to grow into the 2040s, offering lenders demand certainty. This paper assesses the potential implications of WA’s updated domestic gas policy. The state’s domestic gas market is projected to require 8–10 tcf of gas over 2023–50. Currently producing and under-development fields are expected to supply approximately 5 tcf during this period, leaving around a 2 tcf gap to be filled by the onshore resource base and potential new Domestic Market Obligations (DMOs). The paper reiterates the importance of gas in WA’s energy transition and the need to ensure future supply failing which prices could rise to LNG netback or trigger further intervention.

Beetaloo’s gas bounty: potential for LNG exports and domestic supply

Recent drilling in the Beetaloo Basin has yielded promising results for the emerging shale gas play, enabling the explorers to secure funding and establish a range of non-binding commercial agreements. Notably, Beetaloo wells have exhibited initial production rates over 30 days (IP30), spanning from 1.1 to 5.2 mmcf/day, and there is an evident trend of increasing frac stages with each new well as operators continuously optimise stimulation. This research paper presents comprehensive Beetaloo modelling results, encompassing well type curves, a comparative analysis with the renowned Marcellus shale play in the United States (frequently used as a reference point for Beetaloo), production forecasts, economic assessments, and an examination of potential commercialisation pathways. Based on our modelling findings, Beetaloo’s estimated ultimate recovery (EUR) per well ranges from 7 to 14 bcf, with deeper wells into the Velkerri B Shale demonstrating relatively higher productivity. We anticipate that, with full-scale development, Beetaloo could attain peak production rates of 1 bcf/day, supported by a peak annual drilling rate averaging 50–60 wells. Overall, the Beetaloo Basin possesses the potential to recover close to 8 tcf of low reservoir CO2 gas, opening doors to the possibility of liquefied natural gas (LNG) exports reaching up to 4.5 mtpa and domestic gas supplies of around 94 mmcf/day, limited to the existing infrastructure capacity connecting to the east coast gas markets.

A system dynamic model for natural gas safety supply and demand balance mechanism

AbstractThe security of natural gas supply and demand has always been an important topic, and as a result, analyzing and predicting the supply and demand of natural gas has received considerable attention from researchers. Numerous studies have extensively researched the supply and demand of natural gas. The main purpose of this study is to explore the supply‐demand balance mechanism for natural gas security. A system dynamics model is constructed to assess the supply and demand of natural gas in Sichuan Province, China. A new system dynamics model based on domestic gas, production gas, ecological environment and natural gas supply is proposed. The study considers four scenarios: natural development, economic priority development, environmental priority development and coordinated development. The results show that the rapid economic development has led to an excessive environmental carrying capacity, a larger gap between natural gas supply and demand, a decline in the quality of life of residents, and even affected the energy security of Sichuan Province and China. The findings also show that people's overprotection of the environment can lead to slow economic development, which prevents it from achieving its desired goals. The coordinated development scenario in this paper not only ensures the production of natural gas and the quality of life of residents, but also is an optimal scheme with low energy consumption and pollution. According to the research conclusions, considering the overall situation of China's energy security and the situation in Sichuan Province, the author proposes reforms from the supply and demand sides of natural gas.

Problems and prospects for development of the gas industry in the domestic market in 2022

The new conditions for 2022 imply a reduction in natural gas exports from Russia to Europe. We expect an overall reduction in natural gas exports from Russia from 244 bill. cub. m in 2021 to 155 bills. cub. m in 2025. Not only physical export flows, but also financial ones will be reduced, which may change the financial condition of Russian companies and require adjustment of their behavior models and strategies. In such conditions, the development of the domestic natural gas market, which has been discussed for the past 20 years, becomes an extremely topical topic. Therefore, this article will focus on the domestic gas market. The main producers of natural gas in Russia, their operating conditions, tax regulation, access to exports and their role in the domestic market will be analyzed and studied. In addition, domestic gas consumers will be considered and the potential for growth in natural gas consumption in the Russian domestic market, which lies in the growth of the chemical industry and the development of gasification, will be assessed. The article will put forward proposals for rebuilding the existing model of the domestic gas market, such as the abolition of the severance tax on new volumes of gas supplies, expanding the capabilities of independent companies in terms of domestic gas supply and gasification, optimizing approaches to choosing settlements for gasification, allowing all gas companies to export LNG, solving the pricing problem: choosing the optimal model for price liberalization in segments other than households and housing and communal services.

Maximising production from the Gippsland Basin: integrating subsurface datasets across multiple disciplines to increase domestic gas supply

The Turrum Field in the offshore Gippsland Basin has been a significant gas contributor since first development in 2004 and remains a keystone gas resource in the basin. Much work continues to be done to both optimally deplete the current accessible reserves, and to evaluate reserves capture opportunities through additional drilling. A multidisciplinary team of geoscientists and reservoir, production and wells engineers was formed to re-evaluate how to maximise production from the Turrum Field. New seismic data, wireline surveillance, production and surface monitoring parameters were integrated with existing geological models. An enhanced understanding of the Turrum reservoir has emerged with a more informed view of future well work requirements for optimal depletion of the field. The integration of this new information along with enhanced seismic over the greater Turrum area has not only helped to optimise production from the existing wells, it is also supporting efforts to evaluate the potential to fund additional opportunities to optimise production from Turrum, increasing current and future gas supply to the domestic market. The key to success for this work was the integration of many disparate subsurface datasets and the willingness to test biases and challenge previous field development recommendations based on new data and ideas.

PESA Australia Business Environment Review 2022

The energy industry has experienced continued uncertainty in the last 12 months driven by the ongoing impact of the war in Ukraine, China’s continued COVID crisis and the energy transformation. While the impacts of these events have varied across the world regional responses have focussed on energy security, affordability, and decarbonisation. While this has resulted in a greater focus on policy, investment decision making and operational discipline, it has also resulted in discussions at COP27 and DAVOS on energy poverty and the need to ensure equitable access to affordable energy. One important ramification of this uncertainty was the record global capital investment in energy transition activities particularly in renewable energy, electrified transport, and energy storage. From an Australian perspective, against the backdrop of a revised national emissions target and an east coast energy crisis, industry participants attempted to progress capital projects to support domestic energy demand–supply requirements. However, these ambitions were challenged by energy policies, economics, and social activism influences. Consequently, important projects designed to address domestic gas supply constraints were either suspended or experienced postponement of final investment decisions. Furthermore, through the vehicle of mergers and acquisitions, new participants entered the Australian market as established upstream operators actively sort to increase sustainable energy investments through ‘new energy’ business models in the form of portfolio consolidation, divestment, and defensibility as part of the energy transition pursuit and carbon abatement. All of which fosters long-term value creation through the ESG growth space as renewable technologies such as Carbon Capture Utilisation and Storage, experienced significant investment within the local industry. Finally, the unavoidable maturation of oil and gas assets across the nation has also accelerated activities across the Australian market in preparation for the imminent decommissioning wave, which is anticipated to cost billions of dollars over the next decade.

Accident type analysis and consequence simulation of LNG terminals equipment and facilities

A new round of energy change, energy clean and low carbon development become an inevitable trend. In the adjustment of energy structure, natural gas becomes the strongest growth carrier and LNG reserve peak regulation is of great significance. Building liquefied natural gas receiving center to secure domestic natural gas supply has become the main target, task and key work. Through the simulation of various equipment and facilities in the LNG terminal under different leakage scenarios, the accident scenarios are selected according to the protection distance criteria, the simulation of steam diffusion, pool fire, jet fire and explosion is carried out, and the influence range of consequences is obtained. The thesis provides a theoretical basis for the quantitative risk assessment for LNG terminal accident and the prediction of emergencies, having positive guiding significance for risk management and emergency disposal of new or operating LNG terminals.

Potential Analysis and Technical Conception of Exploitation and Utilization of Tar-Rich Coal in Western China

The resources of tar-rich coal in Western China are abundant and are available for large-scale development. Understanding the oil and gas resource properties of tar-rich coal and promoting the development and transformation of tar-rich coal to produce oil and gas are crucial for increasing domestic oil and gas supply, relieving external dependence on oil and gas, and ensuring national energy security of China. This study estimated the potential of tar-rich coal resources in Western China based on the current exploration results of coal resources, reviewed the current status and existing problems, and proposed the basic concept and technical conception for the development and utilization of tar-rich coal in Western China considering the new requirements for carbon reduction, intelligent green development, and compensation for oil and gas shortage. The study concluded that the development and utilization of tar-rich coal needs to focus on key technologies, including high-precision comprehensive exploration, high-recovery-rate mining, underground in-situ pyrolysis, pyrolysis and gasification integration, and in-situ pyrolysis char CO₂ storage. Furthermore, we suggest that the tar-rich coal should be included in the management of unconventional oil and gas resources, scientific and technological research on the development and utilization of tar-rich coal should be strengthened, a national demonstration area should be established, and development of new energy and tar-rich coal in Western China should be coordinated, so as to maximize the special advantages of tar-rich coal as coal-based oil and gas resources and realize the low-carbon and high-value utilization of coal resources.

On ensuring stable natural gas supplies in China and Japan

China and Japan are the two largest importers of natural gas in the world. Both countries have accelerated the reform of domestic natural gas markets and the establishment of domestic natural gas trading centers (natural gas hubs) in order to achieve carbon neutrality goals and ensure the security of domestic natural gas supplies. The conclusion of short- and medium-term contracts for the supply of liquefied natural gas (LNG) affected the execution of long-term contracts, the prices of which were tied to JCC. As a result, Chinese and Japanese natural gas buyers began to demand that international natural gas sellers, including Russia, use hub market prices. The article analyzes measures to ensure the security of natural gas supplies and reforms of domestic natural gas markets in China and Japan. The interrelations, advantages and disadvantages of long-term, short-term and spot contracts are highlighted. Based on the analysis of the court decision in the case of GNA v. Atlantic LNG, the conclusions of international arbitration practice on price revision clauses are summarized. The following conclusions are drawn： 1. Arbitration proceedings on the revision of prices contributes to the transition from a formula for calculating prices linked to the oil price index to a pricing mechanism based on various indices of natural gas hubs.2. When concluding a new long-term contract, it is proposed to comprehensively use the price index of the emerging shopping center, the spot price and the price formula calculated by JCC.3. A long-term contract still plays an integral role in ensuring safe natural gas supplies in extreme events (for example: a similar COVID-19 epidemic).

The prospect of natural gas hydrate (NGH) under the vision of Peak Carbon Dioxide Emissions in China

To achieve the goals of Peak Carbon Dioxide Emissions and Carbon Neutrality, China's energy system will continue to accelerate the transition to a clean and low-carbon one. As the cleanest fossil fuel, natural gas is regarded as an inevitable choice for China to build a clean, safe, efficient, and low-carbon energy system and fulfill the goal of “double carbon”. However, the domestic conventional natural gas supply remains rigid while the stimulation of unconventional natural gas is still limited. If we have a firm grip on the principal line of “understanding the ocean -- developing resources -- ensuring security” to realize the large-scale development of 85 trillion square meters of NGH in the South China Sea, then we could not only greatly reduce China ‘s foreign dependence on natural gas, but also guarantee the safety of China ‘s natural gas multi-path supply and safeguard the sovereignty of the South China Sea. Thus, the goal of Peak Carbon Dioxide Emissions and Carbon Neutrality can be achieved in no time.

A Norwegian Oil Company Could Play a Key Role in Brazil’s Gas Transformation

Equinor could play a critical role in Brazil’s drive to boost its economy by opening up its gas markets. The Norwegian oil company operates two huge deepwater blocks with enough gas to lower prices in the country where big users pay some of the highest prices in the world. The development plan for one of those blocks, BM-C-33 in the Campos Basin, would deliver an average of 14 million m3/d of gas—about 15% of the country’s gas demand on a high-consumption day, which is about 92 million m3/d, based on data from Rystad. A second project in the heart of the presalt, Bacalhau, could become a model for how an international oil company can market gas successfully in the country’s richest oil play, the Santos Basin presalt. The gas potential in that play is also huge; the gas/oil ratio is high compared with other Brazilian fields but has largely been untapped. So far, Equinor and its partners in the projects have not committed to developing gas on either lease, but Equinor appears to be seriously considering doing so. The big question it needs to answer is what the gas market there will look like in a year or so. Brazil has set out to promote domestic gas supplies by ending Petrobras’ virtual monopoly in the pipeline business in favor of a less-regulated, competitive gas market. Equinor avoided gas sales at Bacalhau with an $8 billion Phase 1 plan that will use the popular practice of reinjecting produced gas. Gas reinjection maintains reservoir pressure and allows the development to comply with Brazil’s ban on routine flaring. Brazil’s energy regulator, ANP, said that when Equinor develops a plan for its second phase of development, the company needs to con-sider gas production. The role of gas market pioneer is the latest technical challenge taken on by Equinor in Brazil. Previously, it became the operator of an offshore heavy-oil field—Perigrino—and an aging giant—Roncador—both in the Campos Basin. While the Norwegian company has not promised to take on that role, it has a huge incentive to do so as the operator of Block BM-C-33, where most of the reserves are in the form of gas. The resource is estimated at 3 Tcf of gas and 700 million bbl of condensate, according to Offshore Technology. Equinor and its partners Repsol and Petrobras have developed a plan that would move the liquids by tanker from the platform, which is in water as deep as 2900 m, and build a pipeline about 200 km from there to shore. When asked about the status of the project, Geir Tungesvik, senior vice president for project development at Equinor, said the company is working to “improve the business case.” A Potential Case Study Tungesvik’s bland description fails to reflect the risks and uncertainties faced by those trying to put together offshore gas marketing plans in Brazil. If Equinor and its partners go forward with their plan to monetize that massive gas reserve, the result is likely to be a case study for those who follow. It could either be a model for successful development or a cautionary tale.

Hydrogen for all? Household energy vulnerability and the transition to hydrogen in Australia

Energy supply side policy in Australia currently advocates a role for hydrogen as a key part of decarbonising gas, including in the residential sector. However, there has been little focus to date on demand side issues and, in particular, the impact of a transition to hydrogen on vulnerable consumers. Vulnerability in the energy sector is the result of a complex interplay of structural and individual factors, and there is growing cross-sectoral concern that without careful consideration, existing vulnerabilities may be exacerbated in the low-carbon energy transition. While energy vulnerability in the decarbonisation of electricity has received attention, limited research exists on the potential impacts of a transition to hydrogen fuel in the domestic sector for consumers. At a national level there are plans, and pilot projects underway, to inject hydrogen into domestic natural gas supplies, beginning with low percentage blends of hydrogen and moving towards 100% hydrogen ultimately produced by renewable energy. This project investigated what is currently known, and what still needs to be known, about the potential impacts of decarbonising Australia’s residential gas with hydrogen on energy vulnerability, drawing on existing literature and key stakeholder views from the energy industry, government and social advocacy groups. The findings from this preliminary study reveal critical knowledge gaps in the field which must be addressed if an equitable transition to low-carbon gaseous fuels in Australia's residential sector is to be achieved. Five research options are made to help fill these knowledge gaps.

PENGENDALIAN KUALITAS PRODUK ELPIJI PSO (Public Service Obligation) DENGAN IMPLEMENTASI STATISTICAL PROCESS CONTROL

Domestic Gas Region V is division of the company PT Pertamina Persero which is engaged in providing domestic LPG, especially in the field distribution of PSO and non PSO LPG. Domestic Gas supply LPG through SPPBE (Station for Filling and Transporting LPG Bulk) to agents to direct consumers. Especially for the PSO LPG with a weight 3kg is product of government subsidies with large scale production, it is necessary equalization of good quality for use by the middle to lower class society. In ptactices, many consumers feel that there are several differences between products one another, especially the difference in the weight of the filled tube and the diameter of the valve that is not the same, so ut is difficult to install with the stove regulator and can cause gas leakage which in turn caused a fire. Implementation of statistical process control is carried out to measure the quality of LPG PSO so that it is expected to be able to maintain and improve the quality of PSO LPG products. Statistical process control is done because it exists differences in quality dispersion with the same product this needs to be done to meet the wants and needs of consumers and increase customer satisfaction. This research was conducted to measure the effectiveness/success in controlling and supervision of product quality by implementing statistical process control, the first is to measure the description of the quality of LPG products, the second is to measure how consumer satisfaction with LPG products. The results obtained show that statistical process control analysis illustrates that the performance criteria set by the holding company of PT Pertamina has been very good seen from the P-Chart control which produces the value “P” is in the lower limit of the lower control limit.

Development of Domestic Gas Supply and Utilisation Prices for Effective Gas Distribution in Nigeria

Every resource produced by a country should by necessity satisfy the needs and demands of its populace before consideration is made for export. This will ensure that a country is sufficient in production and allocation of its resources. While Nigeria is regarded internationally as a major gas producer in the world, her local consumption of natural gas is limited due to unavailability of gas for domestic utilisations fuelled by large margins between domestic and international pricing of natural gas. At the international markets, the gas attracts higher price due to market conditions while the prices are relatively lower at the domestic level probably due to limited routes of utilisation of the resource. Because of this, gas producers prefer to sell their commodity at the international market creating scarcity at the local levels. This has heralded underdevelopment of the manufacturing sector and indigenous companies in Nigeria that thrive on natural gas. This situation can be ameliorated by developing a gas price model for effective utilization and distribution of gas in Nigeria. The model will determine the optimum price that producers should sale their gas to make profit and also make gas available locally. In this study, emphasis is made on the development of a domestic gas supply and utilisation price model for effective gas distribution in Nigeria. The model incorporates the cost of producing a unit volume of gas by the gas producer, the energy value of the gas and the quantity of the gas demanded locally. The model is based on the gas produced, utilised, flared, domestic gas requirement and the aggregate price of gas produced for the various companies. Results show that the total revenue accruable from flare is $1.877B/yr which is higher than the total revenue accruable from DGSO deficit which is $0.595B/Yr. Thus, it is better that companies resort not to flaring. Analysis of the results also shows that companies are provided incentive by the model which closes gas deficit gap through a reduction in gas penalty price. Therefore, it serves as direct incentives to companies who meet with their DGSO. The results show that the gas deficit and flare penalty price has a direct impact on the flare penalty.

Whether natural gas consumption bring double dividends of economic growth and carbon dioxide emissions reduction in China?

Rapid development of China's economy is accompanied by a huge amount of carbon dioxide (CO2) emissions. Natural gas consumption (NGC) offers the possibility of achieving double dividends, namely economic growth and CO2 emissions reduction. It is therefore essential to investigate the double dividends of NGC to China's low carbon development. This study establishes one expanded Cobb-Douglas production function and Kaya function, as well as corresponding panel regression econometric models, to evaluate the double dividends of NGC at both national and regional levels by using China's provincial panel data for the period of 1997–2017. The results show that at national level, NGC promotes economic growth and has potential to facilitate CO2 emissions reduction, but with a small share. At regional level, NGC can achieve economic growth in the northeast, the northern coastal and the eastern coastal regions although the increasing share of NGC fails to further stimulate CO2 emissions reduction. NGC impedes economic growth in the southern coastal region and the southwest region, and the increasing share of NGC could not bring CO2 emissions reduction dividend. In the Yellow River midstream region and the northwest region, the impact of NGC on the double dividends is insufficient. In the Yangtze River midstream region, NGC cannot significantly encourage economic growth and CO2 emissions reduction. NGC contributes less to economic growth than coal and oil at both national and regional levels. The high carbon consumption of residents and industries leads to more CO2 emissions, but the CO2 emissions reduction induced by the increasing share of NGC is insufficient. Therefore, it is necessary to improve natural gas supply network, increase monetary incentive to NGC, expand domestic and international natural gas supply sources, and prepare region-specific policies on supporting NGC.

Design and analysis of hybrid domestic gas supply system with biomass energy and hydrocarbons

A new gas supply system for residents was designed, taking puleyuan village as the research object. Aiming at the rural areas with abundant biomass energy and considering the seasonal difference of gas supply to residents, the gas supply system with biomass gasification coupled with hydrocarbons was used. Through the analysis of the system design principle, the calculation of combustible mixture property and the numerical calculation of energy conversion process, the energy efficiency design of the system was analyzed and optimized in this paper. At the same time, the system was evaluated from the economic perspective of energy conservation and emission reduction, compared with those of traditional fossil energy heating. The results showed that the gas supply system could bring considerable economic and environmental benefits, and it was feasible and expansible to implement in the rural areas in the north of China and the southern areas where winter heating was needed.

A consequence analysis study of natural gas consumption in a developing country: Case of India

Natural gas, as the cleanest burning of the fossil fuels is expected to play a significant role in India's future energy mix. This paper presents a modelling approach to quantify the economic and environmental impacts of natural gas utilisation by various sectors in India while the production of domestically sourced natural gas is in decline. One of the most important sectors is the use of natural gas for cooking where the benefits are also evaluated. The long-term impacts of a reducing domestic gas supply is assessed by using the resource-substitution methodology along with a dynamic resource-depletion indicator that is based on decision-making viewpoints. The results show that the replacement of domestic gas with black coal resulted in an increase under the climate change category by 162%, 202% and 234% for the individualist, hierarchist and egalitarian viewpoints, respectively. The paper highlights the prospects for natural gas in India and shows that the growing demand for gas can be met through imports, but it has associated economic and environmental impacts. Further, the paper presents suitable recommendations including policy-related changes such as carbon pricing and subsidy provision schemes to ensure that the growth of the Indian gas market is sustainable.

An Analysis of the Nigerian Gas Sector in Relation to the Policies Legal and Institutional Framework: The Need for Reform

Nigeria is a gas economy with specs of oil in it thrives on its constant exploitation of its oil resources with little regard for the full exploitation and utilization of its gas resources. Nigeria holds an estimated 190 trillion Cubic feet (Tcf) of proven natural gas reserves comprising associated gas and non-associated gas, making her the 9th largest gas reserve holder in the world and the largest in Africa. The road for reforms in the Nigerian oil and gas industry began with the inauguration of the oil and gas implementation committee in the year 2000 under the Olusegun regime which brought out a draft petroleum industry bill which later was changed into various versions before being passed on May 25, 2017. As the petroleum industry governance bill with the creation of a new regulatory NPRC (Nigerian Petroleum Regulatory Agency), which will take over the petroleum inspectorate, the department of petroleum resources, the petroleum products pricing Regulatory Agency. Also, two new companies were created under the bill, which includes; Nigerian Petroleum Assets Management Company and the Nigerian Petroleum Company, where the assets and liabilities of the Nigerian National Petroleum Corporation will be shared by these companies and the National Petroleum Company will operate as a fully independent commercial entity. Before this development, the gas industry in Nigeria lacked proper policies, structure, a regulatory and institutional framework to implement policies. This led to the creation of the Nigerian Gas Master Plan which was a blueprint to ensure a wholly competitive, market-driven domestic gas sector by increasing the supply of gas into the domestic market. This plan led to the National Domestic Gas Supply and Pricing policy coming into place, which brought with it the Domestic supply Obligations (DSO) supported by the Domestic Supply Obligation Regulations, given to various oil producers to close supply gaps in the domestic gas market and institutions such as the Nigerian Gas Company, Gas Aggregation Company of Nigeria were created as major agents to ensure the commercialization of gas in Nigeria’s domestic market. The National Domestic Gas Supply and Pricing Policy were backed up by the National Domestic Gas Supply and pricing regulation. All these policies, regulations, and more have helped in the building up of the gas industry in Nigeria. Also structurally with the aid of the gas network codes, Nigeria will be able to have a detailed outline of its present pipeline system structures all over the country and the work-ability of the systems available. Though we as a nation can boost the West African Gas Pipeline, which is a trans-boundary pipeline system for the exportation of gas to West African countries. Also, there is the Escracvos Lagos Pipeline Systems (ELPS) which transport gas to various power plants within Nigeria. The National Petroleum Investment Management Services (NAPIMS) has assisted in the enhancement of the gas industry and the power sector through its joint venture with various international oil companies for the exploitation of gas and through the DSO scheme supplies gas to various IPPs in Nigeria thereby curbing the current power crisis gradually.