The Gas-to-Power Nexus in Nigeria: Challenges, Prospects and Outlook for Investments

“COVID-19 has shown that no country can respond to a pandemic without power and that energy access, quite literally, saves lives. A lack of energy access has the potential to magnify the human catastrophe from COVID-19 and significantly slow a social and economic recovery from the virus”

The global pandemic has imposed an unmatched challenge on humanity and global economies. COVID-19 is rewriting the future of the global energy landscape in terms of the role of fossil fuels and renewables. Now more than never, societies are under pressure to ensure the existence of cleaner, greener, healthier and more renewable environments in improving the way of life of their citizens and their economies. Even more crucial is the need to ensure cleaner sources of energy in ensuring energy access in line with the global energy transition.

It is therefore no surprise as to why Gas as a fuel source is gaining significant momentum in the wake of the pandemic. Gas remains the cleanest of fossil fuels and growth in demand for gas is on the increase owing to several factors some of which include- gas as a cleaner and preferred fuel for power production, decline in the purchasing power of the dollar, upward price pressure occasioned by a shift in the supply and demand balance as a result of the expansion of global economies, energy price increase occasioned by increased costs of technology required to explore and develop new hydrocarbon reserves in deep offshore locations, (e.g. the Russian Sakhalin province), gas as a traded commodity with spot markets like oil, thus closing the price gap between oil and gas, etc. Most importantly, the increase in gas demand is driven by the global search for cleaner fuels, with gas emerging as the preferable alternate fossil fuel, especially in light of the global pandemic. It has been postulated that gas may be the last of the fossil fuels to be displaced by alternative energy sources.

Nigeria is taking strides to join the trend of gearing up its gas utilisation owing to its vast natural gas reserves and more importantly because of the revenue shortfalls occasioned by oil price volatility. Several policies and incentives are currently being put in place to achieve the country’s gas utilisation objectives, particularly to service the power sector.

Gas as a Feedstock and its Usage

Nigeria is a major oil producer with significant gas reserves, owing to the associated nature of oil and gas production. Nigeria ranks as the 9th country with the world’s largest gas reserves which is currently at about 203.16 trillion cubic feet (tcf) as at June 2020. Non-associated gas fields have generally not been developed since the discovery of oil in 1956 as gas was not considered as a commercial commodity and currently only accounts for about 6% of the nation’s total primary energy supply. Associated gas has generally been flared until the practice of gas flaring started attracting punitive measures as imposed by the federal government.

Although gas production is associated with oil, gas as a fuel source has varied end markets and/or products that can be deployed, some of which include:

?     As an energy source

?     As a feedstock (petrochemical industry)

?     The production of high-value fuels and chemicals such as methanol, ethanol, gasoline and diesel oxygenated fuel blends.

?     Domestic Liquefied Petroleum Gas (LPG)

?     Gas to Liquids (GTL)

?     Small scale Liquefied Natural Gas (LNG)

?     Gas to Power projects

?     Electricity industry

?     Transportation industry

?     Industrial sector- Manufacturing industry

?     Commercial and Residential sectors

?     Agricultural industry, etc.

Nevertheless, gas as a fuel source has not been adequately commercialised in Nigeria due to infrastructure challenges, inability to meet domestic gas demand and gas flaring practices among other factors. In the context of Nigeria, according to the Ministry of Petroleum Resources (MPR), Nigeria flares an excess of 700 million standard cubic feet (SCF) of gas per day from 178 flare sites, which translates to Nigeria losing approximately $10 billion of revenue annually, equating to $2,00 per MMBtu, due to its inability to capture and commercialize flared gas in the country. If flared gas is properly harnessed, Nigeria can produce 600,000 MT of LPG per year and generate 2.5 GW of power from new and existing Independent Power Plants to power the economy.

Therefore, there is an increased pressure to reduce gas flaring practices via the commercialisation of gas resources under the auspice of the Nigerian Gas Flare Commercialisation Programme (NGFCP). Reducing flaring and increasing gas utilization is a concrete contribution to energy efficiency and climate change mitigation.

Of significant importance is the production of gas for the power sector, considering that electricity generation from Nigeria’s grid is largely thermal-based, which means that about 80% of the power plants in Nigeria are fuelled by gas.

The Gas-to-Power Nexus: Status and Challenges

“With the benefit of hindsight, it can safely be said that Nigeria- “the gas province with a drop of oil”- wasted too much time developing its abundant gas resources. Nigeria has the world’s ninth largest gas reserves and yet badly lags behind peer-countries. Much of the gas ought to have been converted to electricity for its teeming population…”

Natural gas plays a key role in the future development of electricity markets, given that it serves as the least cost emission-intensive fossil generation option and in addition, it provides the needed plant operating flexibility to deal with intermittent renewable generation.

The benefits of gas as a commodity have not been fully explored in Nigeria, up until the recent drive by the Federal Government. Gas has always either been re-injected for oil production of flared in quantities surpassing those taken and transmitted by the Nigeria Gas Company (NGC) to the domestic market due to a plethora of issues ranging from inadequate infrastructure, sabotage, insecurity, pricing and allocation of resources to the domestic market, etc. with the power sector being the key beneficiary.

The power sector, though fraught with its own issues has been starved of sufficient gas for power production which if adequately harnessed will close the energy access gap between supply and demand in the Country, currently being managed by the use of private diesel or petrol generators with negative health consequences, as a result of the lack of sufficient gas resources for power production. Gas accounts for 60-70% of the cost of power in Nigeria.

Rahimpour and Jokar compared three methods for recovering the flared gas of Farashband gas processing plant in Iran. These methods are GTL production, electricity generation with a gas turbine and compression and injection into the refinery pipelines. The results showed that the electricity production gives the highest rate of return (ROR), the lowest payback period, the highest annual profit and mild capital investment.

In 2007, the World Bank commissioned a large study by PFC Consulting to examine economic options for associated gas monetization in Russia. Electric power generation and development of gas processing plants were found to be the most efficient ways to use flared gas. In addition, it was concluded that at a netback price of around $1.42 per MMBTU close to 80 % of Russia’s associated gas could be economically recovered.

Despite the analytics and potentials, Nigeria has stranded generation capacity of at least 7,000 MW. For example, the ten Nigerian National Integrated Power (NIPP) projects with a 5,200 MW capacity started in 2004 and only just completed. In addition, 14 utility solar projects scheduled to deliver 1,100 MW are yet to kick off due to tariff considerations and general bureaucracy.

Nevertheless, the Federal Government is keen on strengthening the gas-to-power nexus in the country via various policy initiatives.

·        The Nigerian Gas Master Plan approved in 2008 seeks to stimulate the multiplier effect of gas in the domestic economy.

·        The National Domestic Gas Supply and Pricing Policy 2008, as one of its strategic objectives, seeks to facilitate and ensure low-cost gas access to spur rapid economic growth.

·        The Nigerian National Gas Policy, 2017 seeks to map out strategies for the introduction of an appropriate institutional, legal, regulatory and commercial framework for the gas sector with the intention of removing the barriers affecting investment and development of the sector.

·        The National Gas Expansion Programme (NGEP) Committee which was inaugurated in 2020 by the Minister of State for Petroleum Resources seeks to reinforce and expand domestic gas supply and stimulate demand via various implementation mechanisms, including the recent Framework for Implementation of Intervention Fund of the Central Bank of Nigeria in the Gas Value Chain which aims at stimulating finance and investment in the gas value chain.

The use of gas for power is an important policy goal in Nigeria especially considering that power is an enabling factor to stimulate and promote other industrial developments in the country. The purpose of the gas-to-power strategy is to encourage the use of domestically produced natural gas for power production and thus increase power supply to meet the country’s domestic needs for power. The benefits of gas-to-power are therefore limitless.

Natural gas can be used to supplement/offset base-load power-reducing GHG emissions as it provides consistent and reliable power. In addition, larger scale natural gas power generation could serve as an anchor client for developing large-scale capital infrastructure for pipelines, road/rail and supporting infrastructures in the country.

Current state of Gas-to-Power Projects

With private sector involvement, there have been significant improvements in the gas market. Some notable actors and projects include:

o  Shell Nigeria Gas (SNG) completed the Agbara-Ota Capacity Project in 2019. The gas plant is reported to have increased the country’s gas production and distribution capacity by over 150%

o  Pan Ocean Oil Corporation recently completed the two phases of the Ovade-Ogharefe Gas Processing Plant

o  The biggest gas pipeline project in Nigeria-the Obiafu-Obrikom to Oben (OB3) Gas Pipeline is scheduled for completion in 2021

o  The ongoing Ogidigben Gas Revolution Industrial Park owned by the Nigerian National Petroleum Corporation (NNPC)

o  Ajaokuta-Abuja-Kano-Kaduna (AKK) Gas Pipeline Project which has attracted support from China’s Sinosure and a group of Chinese financial institutions to the tune of $2.3 billion and was flagged off in June 2020 by President Mohammadu Buhari

o  Dangote Complex- $2 billion fertilizer plant with a 3.0 MTPA capacity which depends on natural gas as feedstock.

Gas-to-Power Challenges in Nigeria

“About 145 to 150 BCM gas is flared per year globally, enough to produce 750 billion kwh of power, which is more than the annual power consumption in the entire African continent”

Gas is the primary source of power generation in Nigeria, and the power sector in the country has been affected by insufficient gas supplies to cater to the four gas-fired thermal successor generation companies, the anticipated National Integrated Power Project (NIPP) expected to rely completely on gas, and anticipated gas-fired power generation. Despite the abundant gas resources currently in place in Nigeria, placing it as the ninth largest gas producer in the world, a significant portion of the country’s gas resources have not been converted to electric power.

The insufficiency of gas supplies has resulted in Gas Supply Agreements being made on ‘reasonable endeavors’ or ‘best endeavors’ basis, rather than gas supplies being made on definite quantities governed by stiff take-or-pay provisions. This situation, in turn, has negatively affected the bankability of gas and power projects in Nigeria. The Key challenges in the gas-to-power value chain are highlighted below.

Key Challenges

?     Gas Availability (Demand growth v Feed Gas Supply) stemming from inadequate capital investment

Lack of adequate capital for the needed upstream oil and gas developments owing to the competing political and socio-economic objectives of the government to which the government has to devote its financial resources and is therefore unable to sufficiently fund its interests under the respective Joint Venture/Joint Operating Agreements via cash calls, thus resulting in investment and infrastructural development challenges.

It is estimated that almost 2,000 MW of power is stranded due to gas unavailability, despite the additional 1,000 MW that is also estimated to be stranded due to non-gas related constraints.

?     Gas Deliverability (Inadequate gas transportation and processing infrastructure across the value chain)

There is currently a dire lack of adequate infrastructure to transport gas to power producers coupled with insufficient domestic gas price incentives. Gas Pipeline vandalism exists as a barrier to gas-to-power projects. For example, although repairs on the Escravos-Lagos pipeline that was vandalised in early March 2015 were completed by the end of the month, power plants were deprived of some 1500 MW, contributing to electricity shortages and low generation output.

?     Legal and Regulatory Impediments

There is a misalignment between the legal, regulatory and policy framework across the gas-to-power value chain resulting in a lack of cooperation among key stakeholders in the gas-to-power value chain and a disjointed approach towards the regulation of domestic supply of gas in the country.

There are also regulatory and institutional misalignments between the domestic gas supply industry and the electric power market and policy inconsistencies. For example, differing approaches are employed with regard to price regulation and resource allocation; a major impediment being the inconsistency between the power sector’s price and economic regulation approach which is an incentive based model in comparison with the gas supply industry which remains subject to the traditional cost of service/rate of return model.

In addition, another notable example of divergence is with regard to the Nigerian Gas Transportation Network Code recently released to harmonise the contractual regime for the transportation of gas which was previously governed by gas transportation agreements that made provisions for delivery of accumulated gas at delivery points via dedicated gas transportation and distribution infrastructure. There is a non-alignment of the Code with existing contracts for power generation, thus creating inconsistencies in the contractual framework for gas to power transactions from the perspective of gas transportation for power projects.

Of critical note is the fact that the regulatory and fiscal reforms in the oil and gas industry remain pending with the delay in the passage of the Petroleum Industry and Governance Bill which has dire implications on the government’s aspirations towards the attainment of a coherent gas-to-power value chain.

?     Security, Affordability, Reliability, Commerciality and Pricing of Gas Supply for Power Generation

The power sector in Nigeria is fraught with a debacle of issues across the value chain which have in effect resulted in a liquidity crisis in the sector. The main concern that has plagued the industry since its privatisation in 2013 is the lack of truly cost reflective tariffs, emanating from a series of issues that have resulted in a negative domino effect on the industry. These issues include:

o  Low electricity generation as a result of network constraints in addition to gas infrastructure and pricing issues

o  Baseline Loss Studies (BLS) data as at the time of privatisation were not fed through into the Multi-Year-Tariff-Order in operation, for tariffs to reflect current realities

o  The sculpted nature of the tariffs which allow for under recovery in the early years and over recovery in later years with no adequate means of funding the gap based on the lack of credibility of the Distribution Companies who exist as the last mile agents in the value chain

o  Non-implementation of the various minor reviews which has not led to a ‘true-up’ or ‘true-down’ of the tariffs to reflect current realities based on changes in certain parameters such as generation capacity, inflation, exchange rates and gas costs, foreign exchange pass through costs not recoverable via end-user tariffs

o  Cost recovery and pricing mismatch based on the fact that the pass through costs from the Power Purchase Agreements (PPA’s) between the Nigerian Bulk Electricity Trader (NBET) and the Generation Companies (GenCos) to the Vesting Contracts between NBET and the DisCos are not recoverable via the MYTO tariffs

o  MDA (Ministries, Departments and Agencies) debts running into trillions of Nigerian Naira and not reflected in the collection loss component of the Aggregate Technical, Commercial and Collection (ATC&C) Losses factored into end-user tariffs

o  Lack of willingness to pay by end-use customers as some still view electricity as a social good

o  Technical Losses, Billing Inefficiencies and Electricity Theft leading to increased ATC&C losses, etc.

The cumulative effect of the above listed issues which are not exhaustive has hindered the ability of the DisCos to fulfil their market remittance obligations to the value chain as the last mile collection agents of the industry.

On the gas end of the value chain, the shortage of gas supply continues to prevent the availability of new gas-fired power stations to generate sufficient amounts of electricity. In addition, the lack of an appropriate gas-pricing framework represents a major impediment to the commerciality of gas for power projects, leaving industries with no other option but to self-generate. By legislation, the Federal Government is permitted to approve the price at which gas is sold domestically which may be viewed as being contrary to international best practice, given the high degree of what has been termed as ‘state controlled’ pricing.

Gas producers do not comply their Domestic Gas Supply Obligations (DGSOs) in flagrant disregard of the National Domestic Gas Supply and Pricing Policy 2008 and the National Domestic Supply and Pricing Regulations 2008 and instead opt for the exportation of natural gas.[1]

Participation in the international gas market is usually a juicy sell to domestic gas producers, due to the investment-friendly prices.[2] Gas companies will rather explore LNG export to the international market where there are preferable contract terms and appropriate levels of regulatory certainties and guaranteed reasonable return on investments. This system/practice pushes unrealistically low prices for the domestic market and has created a huge shortage of gas in relation to domestic demand which has in effect halted industrial development across several sectors of the economy, notably the power sector.

In addition, the cost of building additional infrastructure to sell to the domestic market, does not make economic sense to gas producers who do not have to contend with such challenges in the international market. Another disincentive is the fact that in the domestic gas market, gas producers will need to identify credible off-takers beforehand, unlike in the international market where most of the gas is traded in the spot market.

Nevertheless, optimistic propositions exist to the effect that:

-         The illiquidity in the Power sector is addressed and holistic pricing reforms are set in place which is currently ongoing;

-         For the other markets, the FG introduces reforms for the removal of price subsidy to foster a free market interplay such as the recent Market Based Pricing Regime for Premium Motor Spirit (PMS) Regulations, 2020 released by the Petroleum Product Pricing Regulatory Agency (PPPRA) on the 4th of June 2020. The Regulations provides for a system which seeks to deregulate the pricing regime in the sector.

The totality of the challenges impacts the commercial viability of gas utilisation projects, most of which are currently operating on a ‘best-endeavor’ basis hinged on the non-enforcement of securitisation terms agreed between parties, occasioned by the all-round liquidity impediments across the gas-to-power value chain.

Recommendations

Key drivers to encourage investments for gas-to-power include- viable business models, clear policy, legal and regulatory frameworks, scaling up incentives, appropriate value chain pricing, de-risking financing elements, etc.

Ultimately, to attract investments in power projects for increased energy access, the government will need to provide the necessary legal and regulatory framework in the gas and electricity sector(s) to underpin the PPA which typically has a duration of 20 or more years alongside other attendant agreements. Consideration should therefore be given to the following recommendations across the gas-to-power value chain.

?     Infrastructure and Security

Given the government’s policy objectives of building the domestic gas-to-power market, it is pertinent for the government to provide sufficient funding or partner with the private sector for the necessary infrastructural development. However, the government must put in place an enabling legal, regulatory and policy framework to incentivize investment in the sector. In addition, adequate security measures must be put in place to curb the menace of security related activities, one of which is the notorious gas pipeline vandalism, which has a negative domino effect on gas availability and electricity generation output.

?     Legal and Regulatory

The existing legal framework for gas needs to be restructured to align with international best practice by reducing/eliminating the current high degree of ‘state controlled’ pricing which distorts the anticipated benefits from the projected investment outlook for gas production and supply. Alignment is needed between price regulation in the power sector and an integrated and effective consideration of investments and cost outlook for gas supply owing to the interconnectedness of both sectors.

In addition, a unified approach to the regulation of domestic supply of gas in Nigeria needs to be established.

There is also a need for coordination and alignment of institutional behaviour across the gas to power value chain which will save a lot of time for gas to power transactions and also reduce transaction and administrative costs. Duplication of functions and regulatory overlaps will be avoided as there will be more regulatory certainty which will enable the Nigerian Electricity Regulatory Commission project more accurate electricity generation capacity growth.

In the alternative, consideration can be given to the establishment of an independent regulator to manage gas market challenges in conjunction with the power sector regulator or one independent regulator to take up both functions.

?     Governance

There is a need for efficient institutional and governance framework in place to cater to pricing and allocation of gas resources between export (LNG) market and the highly-gas dependent domestic markets with adequate mechanisms in place for the enforcement of domestic gas supply obligations.

Consideration should be given to the establishment of a single independent regulatory authority to formulate appropriate regulation to ensure compliance within the sector. Existing laws and regulations will need to be revised to align with the intent of the various policy objectives of the government. If adopted, the structure of the single independent regulator has to be strategically mapped out to ensure regulatory independence and avoid government influence in the decision making process. Otherwise, the power sector regulator can be tasked to perform dual regulatory functions for gas to power regulation as was done in the UK (OFGEM) and US (FERC).

The long awaited anticipated Petroleum Industry and Governance Bill should be passed into law as the Bill establishes the Nigerian Petroleum Commission to serve as the commission that will consolidate and oversee all upstream, midstream and downstream petroleum operations in Nigeria, of which some of its functions include enforcing pricing frameworks for gas, ensuring that economic and strategic domestic demands for gas are met, and developing market rules for trading in wholesale gas supplies to downstream gas distributors. The Bill if passed into law is set to harmonize and stabilise gas pricing in Nigeria via the deregulation of the downstream sector through the promotion of a market-based pricing regime, which would boost investments in the gas to power value chain. Nevertheless, it is important that the proposed gas pricing framework in the Bill is mirrored in power sector regulation and reflected in the MYTO to ensure uniformity of application. Any pass through costs and risks enshrined in documentation across the value chain must conform and align with the regulatory provisions governing each segment of the value chain to avoid any form of dichotomy that will send a negative signal in the market and deter the much needed FDI in the sector.

The Governance framework should complement and not contradict the framework governing other related sectors such as the power sector.

?     Power Sector

Existing risk factors in the power sector need to be properly managed and mitigated, to enable tangible revenue flows across the gas to power value chain. Pertinent risks in the sector that require urgent attention as earlier highlighted include- non cost-reflective tariffs, government debts (Ministries, Departments and Agencies), low generation and security risks, metering, weak sanctioning regime for energy theft, etc.

It is therefore essential that all contracts (PPA’s and Vesting Contracts) for the sale and purchase of power be activated with adequate enforcement of the performance guarantees and security covers in order to prevent debts amassing which will further hinder investments in gas processing and infrastructure essential for reliability of supply across the gas-to-power value chain. Nevertheless, regulatory and policy consistency is key to align with contractual commitments of the various participants.

The conditions for bankable gas to power projects have to be in place with adequate risk allocation mechanism and enforcement discipline for the gains of gas to power projects to be fully achieved.

?     Gas Pricing, Electricity Tariffs and Incentives

Domestic gas prices can either be subsidised or benchmarked against international prices with domestic cap provisions to promote local gas trading. However, consideration has to be given to the fact that government involvement via price caps on the commodity will hinder the interplay of market forces, thereby discouraging investment. It is proposed that the supply of gas to domestic markets would only be profitable when prices are deregulated, and market forces are allowed to interface and compete alongside the international gas price. There should therefore be strategic plans by the government to open up the gas market for competition by participants to ensure the gains of its policies are realized.

Subsidized competing fuels or electricity prices in some countries frustrates the sale of associated gas or end-products produced from associated gas feedstock into the local market. Reforms for price subsidy removals have to be implemented to foster a free market interplay.

Nevertheless, during the transitional period, although the intention is for prices to be unregulated but rigorously monitored before the wholesale market is fully established, the unregulated prices should bear a cap to avoid discriminate pricing which may be difficult to monitor. Incentives however need to be put in place such as a mix of fiscal incentives, associated gas commercial profit sharing, etc.

An appropriate gas pricing framework needs to be developed for the gas to power value chain to facilitate efficiency in gas supply to power.

Azura-Edo IPP is a case in point. The IPP signed a 5 year gas supply agreement (GSA) with the operators, National Petroleum Development Company (NPDC)/Seplat Petroleum Joint Venture on a ‘willing-buyer, willing-seller’ basis for about 116 million standard cubit feet/day of natural gas. It also signed a Gas Transportation Agreement (GTA) with the Nigerian Gas Company (NGC). Project Risks were allocated based on the principle of ‘allocating risks to the party(ies) best able to bear the risk(s)’.

?     Gas Flaring

The penalty for gas flaring has to be increased to levels higher than marketing or re-injection alternatives. The Flare Gas (Prevention of Waste and Pollution) Regulation, 2018, somewhat compels Producers to commercialize gas through the increased flaring fees which should discourage routine gas flaring which is a step in the right direction.

The Nigerian Gas Flare Commercialisation Program (NGFCP) currently in abeyance is a step in the right direction for gas to power projects.

For Independent Power Producers and Distribution companies within the franchise areas of the respective flare sites, this would provide great advantages. The certainty of gas supply for embedded power projects would ensure the bankability of supply arrangements. This would in turn result in greater economies of scale for parties to Gas Supply Agreements and Power Purchase Agreements. However, it is doubtful that this would result in an increase in revenue due to the Generation companies from the Distribution companies as other determinant factors must be addressed to ensure revenue assurance in the Nigerian Electricity Supply Industry. 

?     Regional and International Pipeline Projects

The government needs to devise strategies that will address the security risks surrounding the West African Gas Pipeline Project particularly with regard to pipeline vandalism especially in light of the proposed African Single Electricity Market. 

The attainment of a viable and functional gas-to-power market is largely dependent on the implementation of the above recommendations, but more importantly on the dual existence of a liberalized gas sector with an appropriate pricing framework and a credit worthy power value chain via the existence of cost reflective tariffs. Ultimately, coordination among the two sectors remains pertinent, in order to maximize and reap the wider economic benefits. Collaboration amongst all stakeholders on energy policies and regulations is therefore paramount.

[1] The National Gas Supply and Pricing Regulations, 2008 contains provisions relating to the Domestic Gas Supply Obligations which are specific proportions of associated and non-associated gas reserves which stakeholders (i.e. gas producers) are mandated to produce and supply to the domestic market. The Department of Gas Resourced assigns domestic supply obligations to each gas producer on an annual basis. Regulation No. 7 stipulates that producers who do not comply with the domestic supply obligations shall be liable to pay for the volumes not supplied and be barred from supplying any gas to export projects.

[2] Although the current cost of domestic gas for power stands at $3.30 (i.e. $2.20 as fuel cost and $0.80 cents as transport cost) which is higher in comparison with the floor price/export price currently at $1.50, other costs are factored into the export price of gas including the transportation tariff, distribution tariff, marketers margin, etc, the cumulative total of which can amount to rates commencing from $7.00 per 1,000 scf, unlike the domestic cost of gas for power which accounts for 60-70% of the cost of power.

List of References

Policy and Regulatory Documents

·        Flare Gas (Prevention of Waste and Pollution) Regulation, (2018)

·        Market Based Pricing Regime for Premium Motor Spirit (PMS) Regulations (2020)

·        National Domestic Gas Supply and Pricing Policy (2008)

·        National Gas Policy (2017)

·        National Gas Supply and Pricing Regulations (2008)

·        Nigerian Gas Transportation Network Code (2020)

Books and Presentations

·        V. E. Eromosele ‘Energy Insight Nigeria- Evolutionary two decades in retrospect’ Centre for Petroleum Information (2020).

·        T. Oyewunmi, I. Ehanmo ‘Energy Law and Regulation in Nigeria- Prospects for Reliable Electricity Supply’ in T. Oyewunmi, P.Crossley, F. G. Sourgens, K. Talus ‘Decarbonisation and the Energy Industry- Law, Policy and Regulation in Low-Carbon Energy Markets’ Hart Publishing (November 2020)

·        I. Ehanmo ‘Taking Advantage of the Flare Gas Regulations (2018) Workshop- Legal and Contractual Considerations for the Commercialisation of Flare Gas’ (March, 2019)

Online Journals and Articles

·        Damilola Ogunbiyi: CEO & Special Representative of the UN Secretary-General for Sustainable, Energy for All (SEforALL) & Co-Chair of UN-Energy.

·        Dr. David Jacobs ‘Policy Brief for the Global Renewable Congress- Making Societies more resilient: the role of renewables in COVID-19 recovery packages’ at https://www.renewablescongress.org/wp-content/uploads/GRC_Policy_Brief_Renewables_in_COVID19.pdf