Eadwig to me it’s just permission at x % above prevailing share price if they need to maybe!!. I could be wrong though!!!.
looks like eroton have a new supervisor for the fso terminal…as they wouldn’t be employing someone like this if oil was still going to be pumped to bonny island via the nctl pipeline…
Eroton Exploration and Production Company Limited
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Location - Lagos
*Years of Experience - Minimum 15 years in similar job role preferably within the upstream Oil & Gas industry (Key Requirement - University degree in relevant Shipping, Marine or Logistics discipline - minimum B.Sc. Hons. Second class upper or HND with relevant work experience)
*Application Deadline - April 10, 2019
Ensure early application and approval of required documentation from DPR in line with internally agreed timelines
Ensure proper distribution of permit to Nigerian Customs, the relevant Crude Oil Terminal as well as DPR
Prepare vessel & crude oil nominations, follow-up clearances, and ensures all administrative work with partners, NNPC & ensure smooth lifting operations at the Terminal.
Prepare all documentation in respect of the Joint Venture partners, liaising with NNPC and Production Department.
Prepare certificates relating to the quality/quantity of all crude oil shipments and ensures that all paperwork associated with shipping activities is efficiently prepared and approved to enable all such activities to precede as planned.
Ensure that all Eroton lifting programmes at the Terminal are efficiently implemented and update the Status Report for circulation to all interested parties as agreed
Carry out all governmental procedures for ensuring openness in crude lifting operations.
Participate in the monthly curtailment pre-meeting activities & meeting attendance with NNPC
Ensure proper documentation with export tanker captain, DPR, Crude Oil Terminal etc.
Attend Quarterly Crude Oil Market Review meetings with COMD and other meetings.
Resolve issues regarding shipped Orders while ensuring compliance to legal regulations and company Policies.
Maintain quality, safety and environmant standards.
Negotiate, develop and manage all commercial agreements to optimise the Company’s commercial interests
Other tasks that may be assigned
Was it in last years AGM - you know, a standard yearly thing? It has to be renewed every year.
Site Survey to Commence This WeekOn August 9, 2019, the Barryroe Partners confirmed that they have received permission from the Minister of State at the Department of Communications, Climate Action and Environment to undertake a seabed debris clearance, environmental baseline and habitat assessment site survey (the “site survey”) over the area of the Barryroe field within SEL 1/11. Whilst the full implementation of the site survey is subject the receipt of the APEC Loan Amount, the Company announced on August 20, 2019 that it had agreed the payment of the contractual mobilization fee. Based on the prepayments made to the Contractor, the Company can now confirm that the vessel has mobilized to Ireland where operations are expected to commence later this week. The projected programme provides for a minimum of two locations to be surveyed at this time with the scope to increase the number of locations upon receipt of the APEC Loan Amount.
Planning ongoing for OML 18 FSO
Partner San Leon Energy has advised that planning has progressed significantly for the installation of a new export pipeline and an FSO to improve production from onshore fields in OML 18.
Operator Eroton is planning to deploy an FSO in order to address the production downtime partly caused by third party terminal and gathering system issues. San Leon has advised that the Nembe Creek Trunk Line (NCTL) was responsible for losses of approximately 15,000 b/d of oil between gross production when the pipeline is running and average sales of oil. The FSO project is also anticipated to improve overall well performance by eliminating the need to restart wells after shut downs. The pipeline will be exclusive to OML 18 and will be connected to an offshore FSO. OML 18 is located in the Southern Niger Delta.
Related Articles16 Jul 2018: Eroton plans FSO for onshore fields
NEWS RELEASE – September 21, 2018
Floater Prospects in the Planning Stage
NEW OML 18 (Nigeria)
NEW Tortue FLNG #2-4 (Mauritania)
NEW Adelaide LNG (Australia)
Doradao / Roc / (Australia)
Flemish Pass (Mizzen / Harpoon / Bay du Nord) (Newfoundland)
NEW Western LNG (Canada)
NEW Liza 4 / Liza 5 (Guyana)
NEW Kelidang Cluster (Brunei)
16/11/2018 · The proposed Alternative Crude Oil Evacuation System (ACOES) project involves the installation of a 47.7Km. 12” pipeline extending from Cawthorne Channel Two (2) flow station within OML 18 to a Floating Storage and Offloading (FSO) platform that would be moored within the marine environment. The proposed ACOES covers coastal waters in the southern parts of OML 18 Eastern
The Barryroe Partners can confirm that Gardline’s M/V Kommandor survey vessel has now mobilized to SEL 1/11 where it will undertake a seabed debris clearance, environmental baseline and habitat assessment site survey (the “site survey”) over the area of the Barryroe field within SEL 1/11. The projected programme provides for a minimum of two locations to be surveyed at this time with the scope to increase the number of locations upon receipt of the APEC Loan Amount. The site survey is expected to take up to 3 weeks depending on operating conditions.
The Group Managing Director of the Nigerian National Petroleum Corporation, Mele Kyari, on Tuesday, said significant progress had been made in the ongoing exploration of inland basins and that the target of growing the nation’s reserve to 40 billion barrels by 2023 was realistic and achievable.
On the commercial level, he said NNPC would continue to meet its cash-call obligations to its joint venture partners on a sustainable basis to enable the international oil companies go back to exploration.
Engr. Chidiebere Hyacinth (MSc, BEng, OPITO, R.Engr, MNSE)
Engr. Chidiebere has a account
Senior Pipeline Engineer at Dover Engineering Limited
Dover Engineering Limited
9 yrs 11 mos
Senior Pipeline Engineer
2018 – Present
I am part of the Engineering Team that executed the following engineering design projects described below:
- DETAILED ENGINERING DESIGN OF ALTERNATIVE CRUDE OIL EXPORT PIPELINE SYSTEM (On-going)
Client: ENERGY LINKS INFRASTRUCTURE (MALTA) LIMITED
Contractor: DOVER ENGINEERING LIMITED
The project scope includes the detailed engineering works necessary for the Procurement, Installation and Commissioning of new 12” x 2.9 km crude oil pipeline from CAWC-3 to CAWC-2 and new 12” x 47 km crude oil pipeline from CAWC-2 to FSO Location for the alternative crude oil evacuation of OML-18 production.
The pipelines are planned to run from EROTON existing facility in Cawthorne Channel 2 (CAWC-2) flow station through the New Calabar River to a proposed FSO location off the coast of Bonny.
DETAIL ENGINEERING DESIGN FOR ALTERNATIVE CRUDE OIL EVACUATION SYSTEM (ACOES)
Mar 2018 – Present
ENERGY LINK INFRASTRUCTURE (MALTA) LIMITED has awarded the Detailed Engineering of the new Pipeline project entitled, Alternative Crude Oil Export Pipeline System to Dover Engineering Limited.
The project scope includes the detailed engineering works necessary for, the Procurement, Installation and Commissioning of new 12” x 2.9 km crude oil pipeline from CAWC-3 to CAWC-2 and new 12” x 47 km crude oil pipeline from CAWC-2 to FSO Location for the alternative crude oil evacuation of OML-18 production.
The water depth at the proposed FSO location is 27.9 m LAT (91.53 ft MSL). The seabed within 100 m of the proposed FSO location is essentially flat. Water depths within the survey area vary from a minimum of -1.21 m LAT (-3.97ft MSL) around CAWC-2 Flow station to maximum of 30.67m LAT (100.62 ft MSL)) towards the South Eastern side of the proposed FSO location.
What Is Saudi Arabia’s Best Oil Strategy?
There appears to be little appetite amongst OPEC members and Russia for further production cuts, despite the gradual slide in oil prices. Russia is reported to have reduced output by slightly less than had been agreed upon by the OPEC plus producer group in August, while OPEC overall saw production up by 80,000 b/d to 29.61 million b/d, according to a Reuters poll published August 30.
Both Iraq and Nigeria boosted output – the former by 60,000 b/d and the latter by 80,000 b/d. The new head of the Nigerian National Petroleum Company, Mele Kyari, said at the end of August that Nigeria could increase output fairly easily next year to 2.5 million b/d, by bringing production stranded by pipeline damage back on-stream.
At the same time, production from Iran and Venezuela appears to have reached minimum levels, while Libyan output is being sustained at around the 1 million b/d mark, despite the ongoing civil war. This means that even if Saudi Arabia can get the OPEC plus group to agree to more stringent reductions, the burden of achieving those cuts will land hardest and squarest on Saudi shoulders.
OPEC’s oil price support via production cuts has always been a double-edged sword. Higher oil prices stimulate non-OPEC oil activity, notably US shale oil, and the US oil patch appears to be struggling. Further OPEC reductions could throw it a lifeline.
The US oil rig count has trended downward since a peak in November last year of 888 to reach 742 at the end of August. The number of bankruptcies is on the rise. Lawyers Haynes and Boone reported in August that 26 US oil and gas producers had filed for bankruptcy so far in 2019, compared with 28 over the whole of 2018.
With high cash requirements to keep production going, shale drillers are finding lending hard to come by in a low-price environment for both oil and gas, the twin products of shale drilling.
This is not the US shale patch burning through its resource. It reflects the over reliance of US shale firms on debt to sustain production. Once market sentiment turns against them, in the form of low expectations of future returns, those companies most over extended are quickly exposed.
Moreover, there is no single breakeven price for US shale.
While some shale production can survive at $40/b and below – the most efficient drillers on the best acreage with the least debt – a WTI oil price under $60/b, combined with Henry Hub gas below $3/MMBtu, and much lower at some regional hubs, also pushes the least efficient drillers, drilling poorer acreage and laden with debt, over the edge.
At the same time, the rapid expansion of US oil and gas production has eaten into the pre-existing slack in the drilling services market. By July last year, the number of available land rigs had dropped to about 18% of marketed rigs and the average day rate for all classes had risen from $14,000 in November 2016 to above $16,000, squeezing drillers’ margins.
This trend has since gone into reverse as drillers exercise more financial discipline and the active rig count drops. But it will take time to restore margin lost to service contractors during the period of rapid expansion.
While Saudi Arabia may interpret signs of fragility on the US oil patch as evidence of the success of its policies, the tendency has been for US retrenchment rather than collapse. Chapter 11 filings may sound dramatic, but the chance to re-order debt means there is seldom the impact on production that might be expected. Drillers pass on the pain to debtors and service contractors, creating a strong incentive to find efficiencies all along the supply chain.
But for Riyadh the current slowdown may be viewed as enough for now when set against the costs of a more dramatic change in policy – a production free for all could pay long term but would have a disastrous short to medium-term impact on petro-economies’ revenues. Further cuts will fall hardest on Saudi Arabia, potentially test to its limits the cohesion of the OPEC plus group, while the benefits will be spread around universally, including to US shale drillers.
The goldilocks zone for Saudi Arabia in terms of achieving a balance between price and market share appears to lie somewhere between $55-$60/b Brent, assuming a $5-6/b premium for Brent to West Texas Intermediate, but in terms of its intended Initial Public Offering for state oil giant Saudi Aramco, Riyadh would prefer an oil price significantly north of $60/b Brent.
Give the current trade environment and growing concern over the health of the US economy, this is not a conundrum Saudi Arabia can currently resolve. A gradual downward drift - barring any flare up in Gulf tensions - might be the best that can be achieved for the moment and preferable to the costs of any dramatic loosening or tightening of policy, the Aramco IPO notwithstanding.