The Shell Petroleum Development Company of Nigeria (SPDC), says allegations of involvement in oil theft at its Bonny Crude Export Terminal is misleading.
A media (not The Tide) had reported that a 2 million barrels crude deficit between 2016 and 2018 reported at the Bonny terminal operated by SPDC had caused a dispute amongst several oil firms that use the oil export facility.
Aiteo Exploration and Production Company claimed that SPDC shortchanged it of 1,022,029 barrels of crude while using the Bonny Crude Export Terminal operated by SPDC between 2016 and 2018.
Aiteo is an indigenous oil firm which acquired OML 29 for US$2.4 billion following SPDC’s 2015 divestment of its 45 per cent stake from the asset.
OML 29 includes the 97-kilometer NCTL which has capacity to lift up to 180,000 barrels per day of crude from oilfields in Bayelsa and Rivers States to the Bonny terminal.
In a statement, made available to newsmen at the weekend, Media Relations Manager of SPDC, Mr Bamidele Odugbesan, described the claim as factually incorrect.
“The crude theft/diversion allegation is also factually incorrect.
“This is a distinct issue that relates to the directive by the Department of Petroleum Resources to SPDC as operator of the Bonny Oil and Gas Terminal, an asset belonging to the SPDC Joint Venture, to implement a crude re-allocation programme between injectors into the SPDC JV’s Trans Niger Pipeline and injectors into the NCTL.
“Crude allocation review and re-allocation is a normal industry practice to re-allocate previous provisional allocated volumes under the directive and supervision of DPR, and this is not an exercise resulting from crude diversion, underreporting or theft at the terminal.
“This industry practice is not peculiar to the SPDC-operated Bonny Oil and Gas Terminal alone and does not translate into any loss of volumes to the Federal Government of Nigeria.
“The re-allocation in issue was initiated by SPDC as operator of the Bonny Oil and Gas Terminal, while the DPR validated and confirmed it for implementation for the concerned oil producers.
“Crude oil production metering and allocation are subject to specific guidelines issued by the industry regulator, DPR. SPDC strictly adheres to these guidelines and the implementation is regularly verified by the regulator,” Odugbesan stated.
This Tiny Country Could Become Europe’s Newest Oil Producer
It is rather rare to see enthusiasm for completely new exploration projects in Europe. The overwhelming majority of OECD countries are either in terminal decline or are looking into ways how to ban exploration altogether. The less-appraised parts of Eastern Europe might still have some potential yet in the absence of oil majors such endeavors risk remaining a lifelong pipe dream. Still, the appearance of a new European frontier can rekindle upstream hopes (even if for a short period of time). Europe’s latest addition to the list of nations willing to tap into their prospective hydrocarbon resources is located in the southeast of the Old Continent, in Montenegro. The small ex-Yugoslav republic with just slightly more than 600 000 inhabitants has witnessed its first offshore well spudded on March 25, 2021. The 4118-5-1 wildcat was drilled in 100 meters of water to a total depth of 6525 meters, some 25km from the Montenegrin shore.
The first offshore Montenegrin well was spudded by the ENI-NOVATEK tandem, with the Italian major taking on the reins of operatorship. Given the geographic proximity, ENI’s interest in offshore Montenegro is quite understandable and was to be expected. In case of any discovery, ENI has the convenient option of accommodating prospective production within its system, the Italian shore is only 500km from the wildcat’s location. The first well is targeting an oil reservoir at depths of 6.5km, implying that the Italian major’s 120kbpd Taranto Refinery might be a safe backstop for any potential crude produced. Along with Total, ENI has been one of the most active drillers in the Mediterranean, marking suchsupergiant discoveries as the Egyptian Zohr or the Cypriot Calypso. Across the Adriatic from Montenegro, ENI has been developing the Aquila field offshore Brindisi,producing medium density crude of some 36° API.
The case for NOVATEK’s participation in an offshore project is much more peculiar, considering that the Russian gas producer has no assets in the Adriatic.Moreover, NOVATEK is on the US’ Sectoral Sanctions Identifications (SSI) List, meaning that equity investments and financing matters are substantially encumbered. Luckily for the Russian firm, offshore Montenegro does not fall under any of the three sanctioned areas, Russian deepwater, Arctic offshore, and shale. Domestically, NOVATEK is heavily focused on gas production on the Gydan peninsula and in the surrounding area, compelling it to seek new niches it can fill, new frontiers that could serve as bases for future growth. In a sense, NOVATEK needs to overgrow its LNG specialization and gain market-relevant competence in other segments, too.
NOVATEK’s first step into the foreign offshore segment took place in Lebanon where it landed two offshore blocks in a consortium with Total and ENI in 2018. In both cases NOVATEK did not lay claims to operatorship, focusing on building up key relationships with Europe’s leading drillers. It seems very likely that it is from the Lebanese joint experience that the Montenegrin drilling ambition branched out into a separate work track. Concurrently, although Montenegro is one of the hottest candidates for EU accession, Podgorica remains beyond the bounds of the European Union. For NOVATEK this is a great boon, as sanctions risk can be negotiated directly with the relevant national authorities, i.e. no involvement of Brussels is required.
Technically,the Montenegrin offshore area has already seen exploration drilling, though that was back in the SFRY (Socialist Federal Republic of Yugoslavia) times, in 1980. Although Yugoslavia was a socialist country with all its peculiarities, it was the US major Chevron that was the operator of drilling operations. The Jadran Juzni (Southern Adria) prospect turned out to wield signs of oil and gas systems which, however, were deemed non-commercial,effectively closing Chevron’s offshore endeavors in Yugoslavia. It needs to be pointed out that the current wildcat is farther off the Montenegrin coast the Jadran Juzni well was only 3km from shore. To carry out the drilling, the ENI-NOVATEK tandem contracted the Topaz Driller, a Panama-flagged jack-up drilling rig. The contract was clinched in July 2020, for drilling operations starting in Q1 2021 and taking up to 180 days.
Up to now the work progress of ENI-NOVATEK seems fairly solid. In late 2018 their contractor has carried out a comprehensive 3D seismic survey on the 4118-5 Block, then the summer of 2019 witnessed a string of hydrophysical and geophysical surveys on the prospects. Having completed this, it was assumed that the spudding of the first well would take place in 2020, however, the coronavirus-triggered chaos upended all plans and effectively delayed the wildcat into 2021. Most probably the Italo-Russian joint venture will drill 2 wildcats. Even if the first well turns out to be completely dry or non-commercial, the second well (expected to be spudded in May-June 2021) is targeting gas plays at lower depths, i.e. the first well’s fiasco does not automatically foreshadow the failure of the second well.
According to media reports, it will take ENI 4-5 months to finalize the drilling of the wildcat and assess the results. Nevertheless, Montenegro’s offshore zone might more activity coming up in the upcoming months. The Greek Energean holds 2 license blocks (4219-26 and 4218-30) and is expected to take a decision on whether it intends to proceed with drilling exploratory wells in its acreage. The data to assess the blocks’ resource bounty is already there, Energean carried out 3D seismic surveying on both blocks in 2019 already. The spark of interest towards its off shore zone might compel the Montenegrin authorities to expedite a 2nd offshore bidding round which would presumably cover the 7 remaining unallotted blocks. There is very little probability that Podgorica will be trying to auction off onshore blocks,especially considering their history of dry wells.
Katona is a contributor.
By: Viktor Katona
‘NCDMB’ll Not Invest In Businesses With Competitive Private Players’
The Nigerian Content Development and Monitoring Board (NCDMB), has said that it only partners with strategic policies and projects that are promoted by the Federal Government and would not invest in oil and gas businesses that have competitive private players.
The Executive Secretary of NCDMB, Engr. Simbi Kesiye Wabote, made the clarification recently when he hosted members of the Women in Energy Oil and Gas (WEOG) Nigeria, led by their President, Dr. Oladunni Owo at the Board’s liaison office in Abuja.
He clarified that the Board would not invest in competitive business areas because such investments would compromise its morale position as a regulatory agency.
“Our role is to act as a catalyst of strategic government policies and programmes and we exit once those businesses become successful,” he added.
He also stated that NCDMB is a regulatory agency and not an interventionist organisation and would not get involved in programmes outside its mandate.
According to him, in line with the Board’s vision to serve as a catalyst for the industrialisation of the Nigerian oil and gas industry and its linkage sectors, the NCDMB has partnered with investors in modular refineries, manufacturing of LPG cylinders, LPG Depots, gas processing facilities, lube oil production plant, and a methanol plant using gas as feed stock.
Speaking further, Wabote listed some policies introduced by the Board to support women in the oil and gas industry to include the inauguration of the Diversity Sectorial Working Group in the Nigerian Content Consultative Forum (NCCF) and the creation of the Women in Oil and Gas Product in the Nigerian Content Intervention Fund (NCI Fund).
He explained that the Bank of Industry (BoI) is responsible for managing the NCI Fund, assessing applications and disbursing loans to approved companies.
He said “the NCI Fund is one of the most successful loan schemes. About 98 percent of the borrowers are paying back because we go through a very rigorous process”.
Dwelling on the Project 100 Initiative of the Board, the Executive Secretary stated that it was designed to nurture 100 wholly owned oil and gas service providers in a competitive and sustainable way through targeted interventions, into larger scale players that create high impact.
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