Wednesday, July 21, 2010

Sea Eagle FPSO, Nigeria - ports.com

 Location Details of Sea Eagle FPSO, Nigeria
Location details

Location details

Timezone:
GMT+1 (Aug 10, 15:04)
Country:
Nigeria, Africa
Currency:
NGN
Phone:
+234 844 753319
Fax:
+234 844 753359


Login to be able to send

Port details

Water location:
Bight of Benin Bay (Bay)
Gulf of Guinea (Gulf)
Wiki:
Contribute to wiki
Anchorage depth:
23.2m - OVER
Cargo pier depth:
N/A
Oil terminal depth:
17.1m - 18.2m
Dry dock:
N/A
Harbor size:
Very Small
Railway size:
N/A
Harbor type:
Open Roadstead
Max size:
N/A
Repairs:
None
Shelter:
Poor
Coordinates: 4°47′60.00″N 5°19′0.00″E


- See more at: http://ports.com/nigeria/sea-eagle-fpso/#sthash.pXxPlRbZ.dpuf

Location details

Timezone:
GMT+1 (Aug 10, 15:04)
Country:
Nigeria, Africa
Currency:
NGN
Phone:
+234 844 753319
Fax:
+234 844 753359


Login to be able to send

Port details

Water location:
Bight of Benin Bay (Bay)
Gulf of Guinea (Gulf)
Wiki:
Contribute to wiki
Anchorage depth:
23.2m - OVER
Cargo pier depth:
N/A
Oil terminal depth:
17.1m - 18.2m
Dry dock:
N/A
Harbor size:
Very Small
Railway size:
N/A
Harbor type:
Open Roadstead
Max size:
N/A
Repairs:
None
Shelter:
Poor
Coordinates: 4°47′60.00″N 5°19′0.00″E


- See more at: http://ports.com/nigeria/sea-eagle-fpso/#sthash.pXxPlRbZ.dpuf

Sea Eagle FPSO, Nigeria - ports.com

Newbuild FPSOs: What Can Go Wrong - Offshore



Construction problems and solutions

Graham Parker
Intec Engineering
To date, purpose-built floating production, storage, and offloading vessels (FPSOs) have been constructed in traditional shipbuilding facilities with existing systems. The construction contracts were typically administered with the pre-conceived contractual culture of a shipyard. The 12 newbuild FPSO contracts for Northwest European waters have been made by the vessel's owner or speculator, either directly with the respective shipyard or with the shipyard as a member of a contracting joint venture. Four are owned by single operators - Gryphon 'A', Kerr McGee; Captain, Texaco; Anasuria, Shell; and Schiehallion, B.P. - in the UK Sector, and five in the Norwegian Sector.
The first true monohull FPSO in the North Sea was the Petrojarl 1, delivered in 1986, and was intended to be a production test vessel with a small crude oil storage capability. As the Seillean was designed and built as a single well oil production system (SWOPS), it cannot really be called an FPSO. The title of second North Sea FPSO therefore falls to Gryphon 'A', which started out life as a speculative build floating storage unit. The role changed during its design development into an FPSO.
The Gryphon 'A' was delivered seven years after Petrojarl 1 and the next newbuild FPSO delivered for the North Sea was the Captain in 1997, another four years later.
Of the 12 newbuild FPSOs now installed or under construction for the North Sea, 10 have been the product of the last four years of FPSO history and designs are still evolving.

Market environment

Until the beginning of the 1960s, the principals in shipowning companies would order a new ship by making a telephone call to a shipyard's managing director. The shipyard's managers would begin to develop the detailed design and order steel materials without a contract being discussed - only the price would have been settled. In the 1950s, even the price would be open to some extent as it would often be "cost plus." The "cost plus," however, would include a gentleman's "plus" based on similar, recent or sister ships, and quite easily calculated. All that would change with the advent of intense worldwide competition from the developing nations and increased inflation. Between these two factors, the numbers of countries still capable of major ship construction has dwindled to a comparative handful mostly in the Far East.
In today's shipbuilding environment, the contracts for trading vessels have become a little more specific, but they still convey some of the mutual goodwill that was fundamental to the old contracts.
The discussions that follow, although targeted at monohull FPSO's, are equally relevant to the construction of other offshore sector floating structures built by a shipyard.
It involves a technical solution that solves a commercial problem and conversely, commercial effort that solves a technical problem. This is singularly applicable to the design and construction activities for newbuild FPSO's due to the early historical phase of their development and the ample opportunities for inspired innovation.

Contracting strategy

Although, in general terms, shipyards seem to prefer fixed, lump-sum contracts attached to a fully detailed engineering package, this is usually not equitable with the current fast-track FPSO field development philosophy. Not being equitable affects both contracting parties. Delays can be caused by poor or incomplete engineering. This also leads to contractual confusion or dissension, which may affect the quality of the engineered vessel. One of the best reasons for the beneficial inclusion of the shipyard in an alliance partnership is a case where the workscope is not sufficiently defined at the time of contract. At this time tolerance and help are needed from the shipyard and contractor, but instead there is often disruptive and unproductive contractual wrangling.
If it is determined that all parties would benefit from the shipyard's inclusion in an alliance or joint venture then further detailed analysis will be required before the final step is taken.

Contract structure

Eventually a construction contract will be offered to the shipyard for signature. It is therefore necessary to pre-define the contract structure and its backing documentation. The Crine Network in the UK has recently published its model "General Conditions of Contract for Construction" to provide an industry basis for major construction. The model contract also has a set of guidance notes to complement its use. The complete presentation is the product of years of work and formulation by the Crine Standards Contract Committee comprised of senior representatives from major operators and the contracting industry. The objective of the Model Standard Contract is to significantly reduce the inefficiencies associated with the repeated drafting and reviewing of contracts. It is also intended to facilitate a greater sense of partnership between operators and contractors and will reduce the need for a full contractual review for each tender.
The Crine Model should form a good basis for conventional contracting relationships. There may be some advantage to be gained in the future by the identification of those clauses that would benefit from specific modification for contracting for the construction of FPSOs and create a modified FPSO version of the model.

Bid invitations

Most shipyards under consideration for participation in a prospective project will be easily identified based on their strong profile and capabilities. In some cases, these features are less apparent. They include, for example, when the first choices are full to capacity, when they have changed their market sector interests, or for any reason they are no longer interested in floating production construction. The list of invitees should be as large as is sensibly possible within the project constraints. A typical prequalification questionnaire will include expression of firm intention to bid request, shipyard facilities and manning levels, current workload and schedules, relevant experience in the sector, ownership and corporate relationships, management systems in existence, quality assurance qualification, safety and environmental records, industrial relations records, financial information and accounts.
The prequalification documents will be vetted and evaluated in order to provide a final list of shipyards to be invited to bid for recommendation for management approval.
The status of the front end engineering completion will determine the shape and extent of the formal bid invitation documentation. This can range from just a collection of functional specifications, the design basis and the environmental and geotechnical data or be a full-blown pre-engineering package.
The depth of this engineering will be measured against the speed the project schedule needs, but all floating production projects will have some degree of grease applied to the schedule for early commercial returns. The FPSO vessel design itself will always have the field development principal critical path straight through it and the front end engineering activities are the first consideration. Any of this engineering pushed into the post-award construction schedule will generally impact the schedule on at least a day-for-day basis.
The bid period will depend on the project schedule, tempered with the bid content and complexity, but will probably be in the 3-6 weeks range, with 4 weeks being the likely median requirement. Miscalculating the bid period will only cause dilution of the quality of the bid in terms of accuracy and technical content. It can also have a greater negative impact on the project than almost anything else except the definition of the scope of work.
In order that supportive and qualitative pricing information responses are received from the shipyards they should generally be instructed to complete a price breakdown matrix. This will allow interrogation of individual line items for credibility and validity by comparison with each competitor's figures side by side. The value of this form of evaluation by the comparison of line item breakdown cannot be overemphasised.
All omissions and deviations from the instructions to tenderers requirements will need to be identified, interrogated, and closed out by the bid clarification process. If the shipyards under consideration are also being considered for fabrication and HUC of the process plant, then this would also be incorporated into the matrix for comparison. Apart from consideration of the price breakdown and total cost the overall evaluation will also consider the following principal aspects of the individual offers; total lump sum price, towage cost and schedule impact, site supervision team requirements, averaged rates for variation, payment schedule and methods, financing arrangements and benefits, construction schedule, process plant capabilities, quality assurance assessment, safety record assessment, financial health report, and simple ranking of all offers.
It is imperative that before any final commercial commitment is given to a short listed or recommended shipyard a multitude of other relevant considerations should be evaluated and satisfied. Initially the following aspects of the management systems should be considered; project management system, management culture, communication abilities, business language, document control, QA/QC organisation, procurement and expediting, certification, scheduling abilities, health and safety, cost control, and pre-outfitting experience. The following physical facilities and resources should be evaluated; current and future workloads, building berths and dry-docks, steelwork prefabrication, pipework prefabrication, berth craneage, outfitting quay logistics, undercover storage, engineering manning levels and abilities, steelwork and outfitting trade levels and experience, electrical and instrumentation resources and experience, and hook- up and commissioning resources and experience.
After consideration of all of the foregoing, the bid evaluation teamleader will conclude the evaluation with a formal bid evaluation and recommendation report. This will include all records of the bid clarification negotiations, shipyard assessment visits, and the normalization factors utilized in arriving at the recommended choice of shipyard.

Post-bid refinement

The recommendation to proceed with a shipyard and acceptance will provide an excellent opportunity to fully refine the design, price, and construction schedule in readiness for final pre-award commitment: The final pre-award discussions and negotiations include design/cost optimisation modifications, final agreed scope of work, contract pricing structure and values, milestone payment values and schedule, rates and units for variation, contract currency and exchange rates, master construction schedule, insurances, P.C. guarantee, and performance bonds.
During this period of refinement and final contract negotiation it is imperative that any concurrent negotiations between the shipyard and other potential clients are careful monitored. The opportunity at this stage for the shipyard to "play-off" one client against another for a schedule slot in the yard is often too good to miss, particularly in a strong market situation. The risk to both clients is obvious and probably schedule critical to all.

Contract payment methods

Until about 40 years ago, all of the world's major shipyards contracted for vessels on an almost cost-plus basis, but then fixed, lump-sum contracts, with penalties, became the norm. The days of fixed, lump-sum contracts may now be over as current contracting strategies reflect some form of alliancing arrangement with others and/or the owner/operator. Some of the FPSO developments recently contracted for consist of joint venture partnerships comprised of contractors whom together will supply the total field development scope of work, from conception to first oil.
This form of contract can be based on the target price contracting mechanism which is founded on the principle of shared risk and reward. Payment of a bonus for early production may also be provided.
The target price itself consists of three main elements; a management fee which includes fixed profit and overheads for the joint venture, the estimated cost of the facilities, this would to be charged to the operator at cost. A contingency provided to compensate the joint venture for those unforeseen events often experienced in an offshore project.
The above costs will be declared at the pre-contract stage and have been clarified and agreed.
If the project is to be completed below the target price level then the joint venture partners and the owner would share the savings on an equal basis and the joint venture would retain the fixed profit and overheads.
Should the final price exceed the target price then the excess costs would be shared on an equal basis between the joint venture partners and the owner. This situation can be limited by a fixed amount, the total of which is termed the cap price, after which the owner would pay 100% of the actual costs incurred without limitation.
The amount between the target price and the cap price is set such that all of the fixed profit and overheads element could be lost by the joint venture partners. All members of the project, whether joint venture partners or owner will have an incentive to minimise expenditure, thereby maximising the cost benefits to all parties. Each partner will also be responsible for the rectification of his own defective work, at no cost to the joint venture or owner.
The estimated cost of the project would be based on contract scope of work, pre-award and intermediate engineering deliverables, design basis and reports. No change to any of these documents, which diminish the requirements of the design basis, would be permissible without the approval of the owner. Similarly, no changes to the contract documentation which reduce the availability or quality of the facilities as agreed during the development of the design would be permitted without approval.
Where such changes are approved, any cost increase associated with increased scope would be added to the target price and similarly decreases in scope would be deducted from the target price.
Design development changes which will not effect the target price will be controlled and approved by the joint venture and finally approved by the owner. Cost savings derived by efficient design development will enable the joint venture to earn proportionally more profit under the target price mechanism, again subject to owner approval.
The fixed overheads and profit for the shipyard's scope within the overall project should be agreed between the partners before contract award and built into the target price. The construction cost compensation for the shipyard as a joint venture partner would be determined by breaking out the obvious components of the vessel and topsides in a way that is fair, sensible and can easily be defined and measured.
An incentive related payment schedule should be developed and agreed and this should act as a motivation device and reflect the shipyard's cashflow profile. A typical milestone-related payment schedule for a target price mechanism construction contract is shown below.

Delivery liabilities

The philosophy for the imposition of liabilities and damages on the shipyard will be based on the commercial losses that would by incurred by the owner, and his partners, in the event of delayed delivery. Although generally the contract will include provisions for termination after a stipulated delay in the delivery date for provisional acceptance they would only very rarely be activated. Recovery of an owner's losses by the shipyard's payment of liquidated damages is generally of more interest and it also acts as an incentive to the shipyard merely in its avoidance.
The delayed contract delivery considerations should be contract schedule inherent delay risks, contract price comfort or risks, delay repercussions on installation windows, rights of termination clauses, liquidated damages free period and activation, per diem liquidated damages value(s), and liquidated damages period and payment limit.
Both parties will have the right under the conditions of contract to raise a variation order request, which may or may not eventually become an approved variation order depending on the particular circumstances.
The shipyard shall not implement a proposed variation order until the owner has approved the order by signature. The only circumstances whereby a variation order may be implemented by a verbal instruction, would be in an emergency endangering life or property or where in the owner's site representative's opinion the safety or integrity of the project is at risk. Even under these circumstances the owner will be required to confirm the verbal instructions in writing within, say, two days.
It is preferable that a very comprehensive list of rates for variation be incorporated into the contract to ease the calculation and acceptance of variation costs. These will include for all likely labour, materials, plant and equipment costs etc. and will aid in the avoidance of contractual confusion.
Depending on the final form of contract and the type of contracting relationship intended to operate with the shipyard, the site team need for local supervision and inspection will vary. This can range from just a handful of personnel on site to 50 or more as has been seen on some recent projects.
A likely initial site team build-up for a project with a comfortable status of engineering at the commencement of the contract would include at least nine men. If it becomes obvious that further presence is required on site for supervision and inspection then the team will be reinforced as necessary, but will increase in any case towards the mechanical completion and pre-commissioning stages. The size of the team will also be dependant on the extent of the process plant scope of work being carried out by the shipyard, if any.
The owner's site representative's role will also vary again depending on the type of contracting relationship and existence or not of partnerships and alliance etc. However, it is usually intended that he will act as the sole point of contract and authority on behalf of those contractually facing the shipyard or the joint venture on site as their representative.

Contract schedule

The shipyard will be bound to produce within 30 days of contract award a master construction schedule consistent with the overall contract schedule. This will be in bar chart format for the design, procurement, construction, installation of equipment, testing and delivery of the vessel and shall identify all interdependencies of the variously related activities. Any delays in the early phases of engineering will inevitably delay the complete project schedule due to the critical path weighting of these activities. Critical path delays can rarely be recovered due to the inherent incompressibility of the activities and their subsequent approval cycles. This is often not recognised early enough, to the detriment of the project.
Total project reporting will be produced on a weekly and monthly basis. The method of reporting will generally be by narrative, activity progress bar chart mark up and globally by percentage progress completion figures against pre-agreed S-curves.
Even if quite dramatic increases in performance were to create excellent steelwork and pipework prefabrication progress, the subsequent activities - painting units, pre-outfitting, and erection of steelwork - are all sequential activities without float. All of these activities are also sequential and on the critical path. This is when the real bottle-necks begin to occur and these are generally irreversible as they deny the ability to complete and precommission systems with obvious consequences.
In the demonstrated delay scenario shown above, in order to recover the schedule by the end of the third quartile in order to meet the original delivery date, it would require that 55% of the work volume be carried out in six months instead of the planned 35%.
One of the most remarkable facts about the average FPSO construction schedule is that the last 1% of schedule progress volume can only be achieved in the last two months and which is 8% of the total schedule period.
The only way to achieve successful construction planning in a shipyard culture is to create a belief in planning at all levels but this has to be bought by spending on effective planning systems or overspending on labour. It is important that when the construction schedule states that "Unit 330 will move from the fabrication shop to the slipway on the Friday of Week 22," that it does. This is not just to satisfy the schedule, but so the workforce, supervision and management can depend on it happening.
Contract success should be relatively straightforward to achieve as it is only dependent on four main factors which are well understood by conventional European offshore fabricators. If they weren't understood then they couldn't even get into the business and they certainly couldn't stay in it without them - they are good engineering capabilities, good fabrication quality systems, reliable schedule achievement, and effective hook-up and commissioning.
However, with a few exceptions, the construction activities of all of the Northwest European FPSOs have met with schedule, quality and cost overrun problems of varying degrees and mixes, most of which we are all aware of. Some have been absorbed and mitigated into the overall project development and some have not. Some have been commercial and technical disasters of frightening proportions even to "well-padded" operators. The rumors and estimated figures have even shown themselves to be well shy of reality when the facts finally leak out.

Author

Graham Parker is Manager of Floating Production Systems at Intec Engineering in Houston. He is a fellow of the Royal Institution of Naval Architects and a Chartered Engineer.

Newbuild FPSOs: What can go wrong - Offshore

The Dominance of the FPSO - Offshore Technology

29 August 2008


The FPSO market is floating the offshore industry’s boat. Gareth Evans dives in to find not only that the sub-sector is strong, but that it's about to get stronger with the promise of innovation.

Thirty years on from their first appearance, floating production, storage and offloading (FPSO) systems still dominate the offshore market, and are unlikely to relinquish their position any time soon.
Innovative technologies, coupled with developments of existing ones, have played a big part in maintaining this standing for so long – not least by enabling new possibilities for future projects to be considered. There would appear to be no imminent shortage of these either.
"More than $40 billion is expected to be spent on 123 floating production systems."
According to a recent report by industry analyst Douglas-Westwood, in the period leading to 2012, more than $40 billion is expected to be spent on 123 floating production systems (FPS), with about 95 FPSOs – accounting for 80% of this capital expenditure (capex) – to be installed around the globe. This represents significantly greater prospects for the sector than the preceding equivalent period, which saw a total of 85 FPS units installed, and is anticipated to see particular growth in floating installations in Asia, Australasia, South America and Western Europe.
Global FPSO expenditure is largely predicated on whether fields are to be developed by redeploying or rehabilitating existing units, converting additional tankers or commissioning new-builds. Within the 2008-2012 window of the Douglas-Westwood "World Floating Production Report", from a market value perspective, the forecast is that Africa, Asia and South America will make up about 66% of the anticipated global FPS expenditure.
In terms of actual installations, Africa and Asia are expected to account for nearly half of the 123 FPS vessels anticipated – 27 and 26 respectively.
Despite the similarity in unit numbers, their regional value is somewhat different. Africa’s expected capex has been put at $11.6 billion, reflecting the necessity of new-build and higher-spec vessels, which tend to be required in those waters.
In the case of offshore Asia, the shallower waters and more hospitable conditions allow relatively cheaper solutions to be implemented; the capex is expected to be more than $4 billion lower.
Secrets of success
Part of the reason for the enduring hold of the FPSO approach on the market’s leading edge lies in its simplicity. An offshore production facility capable of accumulating and storing oil before periodically offloading it to tankers for transport to the mainland has obvious logistic and economic appeal.
Not only does this directly permit the rationalisation of shuttle tanker movements but, more fundamentally, it can also allow marginal oil fields, or those in deepwater areas at some physical distance from existing pipelines, to be developed. For the former, their ease of redeployment once economic viability is exhausted is the key, while for the latter, the cost of de novo submerged pipelines is obviated.
However, much of the secret of FPSO success lies in technological innovation. The era of floating production began in 1975, when a converted semi-submersible drilling rig – Transworld 58 – was deployed as the world’s first FPS on the Argyll field in the North Sea, offshore UK.
Two years later, the first oil FPSO appeared on the Shell Castellon field, operating in 117m of water in the Spanish Mediterranean. Since then, the concept of floating production has blossomed, with the arrival of tension leg platforms (TLPs) and spars to add to the original floating production semi-submersible (FPSS) and FPSO fore-runners.
Nevertheless FPSOs have made the greatest inroads and, accounting for 63% of all FPS installations, they remain the dominant force in the global floating production landscape.
Technology advancements since their inception have seen the arrival of a host of features, from geostationary turrets to allow the vessel to turn and ride prevailing weather, to the wider inclusion of water or gas injection and gas-lifts. In November 2006, plans by Petrobras were approved to bring FPSO to the Gulf of Mexico for the first time – on the Cascade/Chinook project in Walker Ridge, in about 2,500m of water.
The development plan calls for the application of a series of technologies new to the region – including a disconnectable turret, subsea electric pumps, free-standing hybrid risers and a mooring system made from polyester.
A year later, in 2007 – with nearly 190 FPSO systems installed worldwide and the role of oil FPSO firmly established – the first LNG carrier conversion to an LNG floating storage and regasification unit was carried out at Singapore’s Keppel shipyard. Recently, concept designs for full LNG FPSOs have also been advanced to produce, store and periodically offload LNG, natural gas or condensate.
The Norwegian company Flex LNG expects its purpose-built vessels – on order with Samsung Heavy Industries – to be producing LNG by 2011, liquefying natural gas with deck-mounted nitrogen expander liquefaction cycle trains.
The technological developments that have cemented the position of FPSO to date remain a powerful guarantee of its continued popularity but there are a number of contingent factors that have formed drivers on its success.
Circumstance and happenstance
The circumstances within the wider offshore industry itself have provided some of the impetus for the continued growth in demand for FPS in general, and FPSO in particular. The gathering pace of expansion unfolding in the uptake of subsea production technologies has been instrumental in this, as has the trend towards operations in deeper waters.
Added to this, economic pressures have altered the perception of marginal fields – and prioritised maximising the extraction from maturing ones – while there has also been an upsurge in interest in fast-tracking projects and phased delivery programmes.
"Economic pressures have altered the perception of marginal fields."
Part of the reason for the rapid expansion of the global FPSO fleet lies in the rising demand for drilling units that has arisen as a result, which has led a significant decline in recent years in the numbers of semi-submersible rigs available to be converted to FPSS. Conversely, changes to international regulations on maritime pollution will soon make all single hulled tankers obsolete in their original role.
The opportunity to reuse these effectively depreciated assets is a strong incentive to refit them as FPSO vessels. Accordingly, such conversions are expected to make up more than half of the prospective units forecast for deployment around the world in the next five years.
Opening new markets
With the first FPSO installation in the Gulf of Mexico poised to begin production 265km offshore Louisiana in 2010, technological development again stands on the brink of opening this new market – which has historically been wary of the approach. Many eyes will be on how well disconnectable FPSO performs here, as the Gulf's deepwater and ultra-deepwater industry continues to look for ways to avoid inherent climatic and economic risks.
In August 2005, Hurricane Katrina damaged or destroyed 30 oil platforms, caused the closure of nine refineries and slashed production in the region. The appeal of being able to simply disconnect, avoid damage and then restart production swiftly is clear.
However the necessary systems have not come cheap, since expensive riser towers or hybrid risers were the only choice for deep and ultra-deepwater FPSO applications. With the advent of technologies such as the recently announced MoorSpar system from SBM Atlantia, all that is changing.
Using lower-cost, higher-efficiency steel catenary risers (SCRs), this new-generation of disconnectable mooring could pave the way for significant FPSO in-roads to the Gulf’s developments – either as long-term solutions or during production start-up. If so, given that projects in the Gulf of Mexico can have relatively short lead times, the area’s predicted activity for the period to 2012 might end up looking conservative.
FPSO’s dominance is nowhere near being over yet.
 
  The Gulf of Mexico: the first FPSO installation is due to begin production here in 2010, potentially paving the way for further use of the technology.
 
  Technological innovation has been behind many successful power and automation projects for major FPSO conversions.
 
  Hurricane Katrina in the Gulf of Mexico: 30 oil platforms were damaged or destroyed, nine refineries were closed and production in the region was slashed. Disconnectable FPSO could herald a new age of catastrophe avoidance for the industry.

The dominance of the FPSO - Offshore Technology

Tuesday, July 20, 2010

Power Supply

Power supply
The Nation 20/07/2010 07:50:00


VICE-President Namadi Sambo has in recent time been raising expectations that the nation will soon begin to see flickers of light in the dark tunnel of despair that has been the troubled power sector.

Only last week, he announced the imminent revival of the stalled Mambilla Hydro Power project in Gembu, Taraba State, when he directed the consultants to produce a revised programme, including the feasibility of the dams within two weeks.

Apparently buoyed by the interest of international finance institutions, the Federal Government is pressing for the revival of the project, initiated 28 years ago, and which, on delivery, is expected to add 2,600MW electricity generation to the grid.

While the Africa Development Bank (ADB) is pledging $3 billion in credit package, the Islamic Development Bank (IDB) is putting forward $2 billion to boost power generation in the country.

Such windows of finance, even if they represent tiny droplets in the ocean of the nation’s needs, certainly count for something. They reflect the increasing willingness of international credit institutions to help Nigeria out of her problems, an opportunity too good to miss, provided the funds would be properly utilised.

Undeniably, under-investment in the sector is at the heart of the current problems in which the nation could barely boast of 4,000MW in power generation. To this is added the problem of poor planning and the well known factor of corruption. All of these explain why expenditure in the last decade has not translated into value in terms of improvements in the power situation – despite the record spend of an estimated $16 billion.

The potential of the Mambilla project is hardly the issue here; we are for the diversification of the sources of energy –be it solar, wind, coal, thermal or even nuclear energy, to guarantee the nation’s sufficiency in power supply. Indeed, we believe that several opportunities currently exist, waiting to be harnessed in the quest to supply Nigerians with electricity.

The issue with such ambitious projects is whether the benefits to be derived actually measure up when weighed against the costs that would be sunk. At the present, there are no indications as to how much it would cost to bring the project into fruition, aside government’s admission that there are technical, logistical and even legal challenges to be tackled along the way.

Even if we rest on government’s assurance that the project will deliver on its promise, what about questions of costs?

Also, we cannot ignore the fact that there are too many loose ends in the power sector that need tying up. Whether in generation, transmission or even distribution, there are still, countless problems in the chain that need to be addressed urgently. The status of the much touted National Integrated Power Projects (NIPP), for instance, remains largely unknown; the same holds true of the gas supply situation so critical to fire the plants.

Important as putting new investments are, the requirement to create synergies among parts to optimise service delivery must be seen as equally compelling. One would have expected that a clear roadmap would have been put in place by now to enable the critical stakeholders key into the government’s reform agenda. Surely, we can no longer afford to grope in the dark.

Just as government has admitted, much work still needs to be done to make the project a reality. Because international finance is involved, the government cannot afford to bungle the project as it did with similar well conceived projects in the past. It should not allow it to become another white elephant project, a monument to service the infrastructure of corruption. Nigerians of course deserve to know the details about the proposed Mambilla hydro project.

CBN Gets Power To Clean Up Banks

CBN gets power to clean up banks’ N1.5tr toxic assets
Vincent Ikuomola 20/07/2010 00:49:00



The Central Bank of Nigeria (CBN) Monday got the legal muscle to clean up the banks and its N1.5 trillion toxic assets.

Top officials of the apex bank exchanged back slaps after President Goodluck Jonathan signed into law the Asset Management Company of Nigeria (AMCON) Bill that will set in motion the final resolution of the banks’ non-performing loans.

The Bill was long awaited, pushed by CBN Governor Sanusi Lamido Sanusi as part of the amortisation strategy to get something back for shareholders and depositors.

Sanusi said after the ceremony that the stage is now set for the final phase of the resolution of the banking crisis, adding that: this is also the tool for clearing up the banks’ balance sheets to ensure that they put the past behind them and move to the new dispensation.

The President said the Bill would ensure the stability of Nigeria’s financial sector.

"I sign this bill today in full recognition of the critical role that AMCON will play in achieving these two critical objectives for our economy," President Jonathan said at the brief ceremony at the Presidential Villa, Abuja.

The law takes immediate effect.

The President, who spoke after signing the bill into law, said once it becomes fully operational, it will help to stimulate the recovery of the financial system from recent crisis by boosting the liquidity of troubled banks through buying their non-performing loans, helping in the recapitalisation of banks in which the Central Bank of Nigeria (CBN) was forced to intervene and increasing access to restructuring/refinancing opportunities for borrowers.

AMCON, Jonathan said, will also help in boosting confidence in the banks’ balance sheets and Nigeria’s credit and risk ratings, restore confidence in Nigeria’s capital markets and prevent continued job losses in banking.

The company, according to the President, is a manifestation of the Federal Government’s commitment to safeguarding the interests of depositors, creditors and other stakeholders in the financial system.

President Jonathan praised the Federal Ministry of Finance, the Federal Ministry of Justice, the CBN and the National Assembly for the effort they put into the preparation and passage of the bill and expressed hope that its signing into law "will be an important turning point in our return to strong economic growth and financial system stability".

The Minister of Finance, Mr. Olusegun Aganga, who spoke to reporters at the end of the ceremony, said the next step is to establish the management team.

"Now that the new law is in place we have the instrument to operate with. The next step will be to establish the Board, the management team and to start engaging with the banks. We are now going to get in to proper operations. The legal frame work has been signed by the President and we are ready to go," the minister said.

Sanusi said the President basically re-affirmed his commitment to cleaning up banks’ balance sheets and for restoring confidence in the capital market and returning the country to the path of growth.
 

Tuesday, July 6, 2010

Nigerian National Petroleum Corporation

NNPC Towers
Herbert Macaulay Way, Central Business District
Garki Abuja
Nigeria
Telephone: (234) 9 523-9141
Fax: (234) 9 234-0029
Web site: http://www.nnpc-nigeria.com

State-Owned Company
Incorporated: 1971 as Nigerian National Oil Corporation
Employees: 15,000
Sales: $2.6 billion (2005)

NAIC: 211111 Crude Petroleum and Natural Gas Extraction; 211112 Natural Gas Liquid Extraction; 213111 Drilling Oil and Gas Wells

The Nigerian National Petroleum Corporation (NNPC) is the holding company that oversees the Nigerian state's interests in the country's oil industry. The company is composed of four main operating units: Refineries and Petrochemicals; Exploration and Production; Finance and Accounts; and Corporate Services. Oil production is the cornerstone of Nigeria's economy—the country ranks as the largest oil producer in Africa. A total of 95 percent of the country's foreign exchange revenue stems from NNPC's operations. Oil operations account for 20 percent of the country's gross domestic product and NNPC is responsible for nearly 65 percent of the government's budgetary revenues. After 16 years of military rule, democratically elected Olusegun Obasanjo took office in 1999. Since that time he has worked to reform the oil and gas industry in the country.

Early History of Oil Industry in Nigeria

Oil was first discovered in Nigeria in 1908, and exploration proceeded during the 1930s in the form of the Shell-BP Petroleum Development Company of Nigeria Ltd. (Shell-BP), under the control of Shell and British Petroleum (BP). Commercial exploitation of the country's reserves, however, did not begin until the late 1950s. The Nigerian government introduced its first regulations governing the taxation of oil industry profits in 1959 whereby profits would be split 50–50 between the government and the oil company in question, and the industry grew during the 1960s as export markets were developed, predominantly in the United Kingdom and Europe. By the mid-1960s, Nigeria began to consider ways in which the resources being exploited by Western oil companies could better be harnessed to the country's development, and formulated its first agreement for taking an equity stake in one of the companies producing there, the Nigerian Agip Oil Company, jointly owned by Agip of Italy and Phillips of the United States. The option to take up an equity stake—in effect the first step toward the creation of the NNPC—was not, however, exercised until April 1971.

By 1971, other factors were pushing the Nigerian government toward taking the stakes in the Western companies that would constitute the basis of the NNPC's holdings. One was the Biafran war of secession, which began in 1967. The support given by one French oil company to Biafra, within whose territory some two-thirds of the country's then-known oil reserves were located, led the federal government to question the contribution of the foreign oil companies to the country's development. So, too, did the companies' unimpressive record in assisting transfer of technology, in social development, and in the employment of indigenous staff. The overriding factor was probably Nigeria's decision to join OPEC in July 1971, obliging the government to take significant stakes in the companies producing in the country.

Formation of Nigerian National Oil Corporation
in 1971


This combination of pressures led to the formation of the Nigerian National Oil Corporation (NNOC) on April 1, 1971. The NNOC acquired a 33.33 percent stake in the Nigerian Agip Oil Company and 35 percent in Safrap, the Nigerian arm of the French company Elf. After Nigeria joined OPEC, NNOC acquired 35 percent stakes in Shell-BP, Gulf, and Mobil, on April 1, 1973. Also in 1973 it entered into a production-sharing agreement with Ashland Oil. On April 1, 1974, stakes in Elf, Agip/Phillips, Shell-BP, Gulf, and Mobil were increased to 55 percent and, on May 1, 1975, the NNOC acquired 55 percent of Texaco's operations in Nigeria.

The NNOC had been established under the terms of the government's Decree no. 18 of 1971. Its brief was to "participate in all aspects of petroleum including exploration, production, refining, marketing, transportation, and distribution." More specifically, the corporation was given the task of training indigenous workers; managing oil leases over large areas of the country; encouraging indigenous participation in the development of infrastructure for the industry; managing refineries, only one of which was operational at this time; participating in marketing and ensuring price uniformity across the domestic market; developing a national tanker fleet; constructing pipelines; and investigating allied industries, such as fertilizers.

This was an ambitious set of objectives, several of which were only just beginning to be realized in the 1990s. The problem that the NNOC faced from its inception was that of attempting to manage a highly complex industry without adequate technical and financial resources, problems that were to be dramatically illustrated several times during its subsequent history.

The NNOC had limited powers as a public corporation. It could sue and be sued, hold or purchase assets, and enter into partnerships. It could not borrow funds or dispose of assets without the specific approval of the commissioner of mines and power, and any surplus funds had to be disposed of at the commissioner's discretion, subject to the approval of the ruling Federal Executive Council. Any activities beyond the scope of Decree no. 18 required government approval, and the government was well represented on the NNOC's board, which was chaired by the permanent secretary of the Ministry of Mines and Power. Other board members included representatives from the ministries of Finance and of Economic Development and Planning, the director of Petroleum Resources in the Ministry of Mines and Power, the general manager of NNOC, and three other representatives with special knowledge of the industry. Thus, from the very start, a body that was seen as crucial to the future prosperity of the nation was subject to close government control, a feature of its operation that has remained throughout its history.

The NNOC operated a number of subsidiaries during the 1970s, including those in exploration and production, refining and petrochemicals, distribution and marketing, transportation, and equipment and supplies. Its success was perhaps most marked in the export field. Boosted by the sharp price rises that followed the first oil shock of 1973, Nigeria saw its oil export earnings rise from NGN 219 million in 1970 to NGN 10.6 billion in 1979, thereby achieving an enviable status as the first tropical African country successfully to exploit its oil reserves.

Becoming a Corporation in 1977

The NNOC was reconstituted as the Nigerian National Petroleum Corporation (NNPC) on April 1, 1977, just six years after it had been set up. One reason for the change may have been the operating failures of the 1970s, which became publicly known at the time of the 1980 Crude Oil Sales Tribunal. This investigation revealed that, for instance, from 1975 to 1978 the NNOC and NNPC had failed to collect some 182.95 million barrels of their equity share of oil being produced by Shell, Mobil, and Gulf—with potential revenue estimated to be in excess of $2 billion. This situation had arisen because NNOC was unable to find buyers for its oil at the price it wanted. It had, however, paid the full share of operating costs to the producers during the period of deemed operation. An additional revelation was that, until forced to do so by the Tribunal, NNOC had not produced audited accounts from 1975 onward.

The NNPC felt the brunt of the Oil Sales Tribunal investigations only three years after it was set up. While some of the criticisms related to events that had occurred before the change in name, the NNPC's practices undoubtedly bore more than a passing resemblance to those of its predecessor. Like the NNOC, the NNPC began life essentially as a holding company. Decree no. 33 vested the assets and liabilities of the NNOC in the NNPC, and conferred on the new body responsibility for some functions of the Ministry of Mines and Power. NNPC also had some additional commercial freedom as the ceiling on contracts that it could award rose 50-fold and it was granted limited borrowing powers. Its board structure was similar to the NNOC's, although the federal commissioner for petroleum replaced the permanent secretary of mines and power as chairman. Judging by the inefficiencies in its record-keeping and its error in overstocking in 1978 in anticipation of oil price rises, greater freedom did not bring with it a greater commercial astuteness.

Also established by Decree no. 33 as part of the NNPC was the Petroleum Inspectorate, which was given responsibility for issuing licenses for various activities, for enforcing the Oil Pipelines Act and the Petroleum Decrees, and for other duties. The chief executive of the division was nevertheless free from control by the NNPC board and reported to the commissioner for petroleum.

In line with the objectives of the government's 1977 Indigenization Decree, the NNPC's holdings in the oil industry operations in Nigeria increased significantly on July 1, 1979, when its stakes in the Nigerian businesses of the following companies were raised to 60 percent: Elf, Agip, Gulf, Mobil, Texaco, and Pan Ocean. NNPC's stake in the Shell venture was raised to 80 percent on August 1, 1979, after BP lost its 20 percent stake following disagreements with the Nigerian government over South Africa. Later that same year a number of accusations originating in the magazine Punch, alleging various forms of misappropriation, broke over the corporation, prompting the newly installed civilian President Alhaji Shagari to broadcast to the nation and establish the tribunal that uncovered the lax management practices referred to previously.

Company Perspectives:

The Nigerian National Petroleum Corporation (NNPC) is the driving force behind the economic development of Nigeria, providing fuel and feedstock for the nation's industrial facilities and meeting the energy needs of individual customers and commercial enterprises. NNPC is the major revenue earner for the nation. NNPC's operations span the length and breadth of Nigeria and involve the entire spectrum of the petroleum industry.

Problems Leading to Reforms in the 1980s

A further setback to the reputation of the Nigerian oil industry occurred at the start of 1980 with the Funiwa-5 incident. A 14-day blowout at an offshore well 60 percent owned by NNPC, but operated by Texaco, spilled 146,000 barrels and may have been responsible for the deaths of 180 people and illnesses among a further 3,000.

The outcome of the Oil Sales Tribunal was a series of reforms designed to decentralize the NNPC. Nine subsidiaries were established in 1981: the Nigerian Petroleum Exploration and Exploitation Company; the Nigerian Petroleum Refining Company, Kaduna Ltd.; the Nigerian Petroleum Refining, Company, Warri Ltd.; the Nigerian Petroleum Refining Company, Port Harcourt Ltd.; the Nigerian Petroleum Products Pipelines and Depots Company Ltd.; the Nigerian Petro Chemicals Company; the Nigerian Gas Company Ltd.; the Nigerian Petroleum Marine Transportation Company Ltd.; and the Petroleum Research and Engineering Company Ltd. The decentralization of Nigeria's three refineries, two of which had been built in the late 1970s and early 1980s, was intended to promote competition and the establishment of this number of subsidiaries was designed to instill a more commercial approach in a more diversified corporation. The goal of diversification was, however, one that the NNPC was slow to realize.

The 1980s did not see an end to close government control and to controversy over the performance of the NNPC. The oil sector took a beating in the 1982 oil glut, when the oil companies' offensive against OPEC targeted Nigeria as the weakest of the producing nations. There were self-inflicted problems as well. Once again, management of the corporation was tainted by scandal, this time involving the former Petroleum Resources Minister Tam David-West, who was jailed at the end of 1990 for his part in another dispute over foreign oil companies. David-West's bad relations with the government were partly responsible for the imposition of direct control of the NNPC by the Ministry of Petroleum Resources between 1986 and 1989. Relations with the foreign oil companies were marked by the 1986 Memorandum of Understanding, which set a profit limit of $2 per barrel.

The end of the 1980s saw a number of initiatives that had the potential to see the NNPC established on a more commercially oriented footing. In March 1988, another new structure was unveiled for the corporation, described by Nigerian President General Ibrahim Babangida as establishing the NNPC as a "financially autonomous" and "commercially integrated" oil company. Petroleum Resources Minister Rilwanu Lukman defined three areas of responsibility for the corporation—corporate services, operations, and petroleum investment management services—and 11 subsidiary companies: the Nigerian Petroleum Development Company, the Warri Refining and Petrochemicals Company, the Kaduna Refining and Petrochemicals Company, the Pipeline and Products Marketing Company, the Hydrocarbon Services of Nigeria Company, the Engineering Company of Nigeria, the Nigerian Gas Development Company, the LNG Company, the Port Harcourt Refining Company, the Eleme Petrochemicals Company, and the Integrated Data Services Company. At the same time, a new sales policy was introduced, eliminating middlemen and setting out three types of purchasers to which the NNPC could sell its products: joint venture producing companies, foreign refineries in which Nigeria has a holding, and indigenous and foreign firms exploring in Nigeria. Aret Adams was appointed as the group managing director and, in February 1989, a new board was constituted, headed by Lukman.

The determination to eradicate subsidies to NNPC and to have it function commercially, rather than as a revenue-raising and development corporation, was apparent in the decision in June 1989 to sell 20 percent of its holding in the Shell joint venture. NNPC reduced its holding to 60 percent, selling 10 percent to Shell and 5 percent apiece to Elf and Agip, in a deal that may have netted the corporation as much as $2 billion. The money raised from the equity sale was to underpin the expansion in reserves (to 20 billion barrels a day) and in output (to 2.5 million barrels a day), to which Nigeria was committed up to 1995. These targets, however, were likely to require the divestment of further holdings to raise cash, and such divestments could not be assured in the uncertain political future faced by Nigeria. As a 60 percent stakeholder, NNPC had persistent problems in raising its share of any development costs.

One positive development was the increasing involvement of the corporation in the development of Nigeria's gas resources. Having been granted a monopoly over gas transmission, the NNPC was well placed to participate in the gas industry. Its 60 percent holding in the LNG Company (Shell owned 20 percent, and Agip and Elf each owned 10 percent) was the springboard for an ambitious $2.5 billion liquefaction project. In addition, Nigeria's fourth refinery, at Eleme, was commissioned early in 1989 and provided the basis for the expansion of a petrochemicals and plastics industry during the 1990s. In its core activity of oil production, NNPC's partner Mobil was developing the large 500-million-barrel Oso oil field, and Nigeria stood to benefit from the environmental attractions of its low-sulfur oil product.

Key Dates:
1908:
Oil is discovered in Nigeria.
1971:
Nigeria decides to join OPEC; Nigerian National Oil Corp. (NNOC) is created.
1977:
NNOC becomes Nigerian National Petroleum Corp. (NNPC).
1981:
NNPC decentralizes into nine subsidiaries.
1999:
Nigeria adopts a new constitution; democratically elected president Olusegun Obasanjo is inaugurated.
2003:
The government begins to deregulate fuel prices and announces that its four major oil refineries will eventually be privatized.
2005:
The company signs a $1 billion contract with Chevron Texaco Nigeria to construct the Floating, Production, Storage, and Offloading Vessel (FPSO) for the Agbami deep offshore oil field.

The period since 1988 was not entirely positive for the NNPC. The plan to market oil products through co-owned refineries overseas did not fully mature. Only one joint venture deal was signed in 1989, with Farmland Industries of the United States, enabling NNPC to make use of a 60,000-barrels-per-day refinery at Coffeyville in Kansas. This was a landlocked site, however, that was not entirely suitable for operations. Of greater concern was the strong possibility that the state did not relinquish its desire to exercise control over NNPC's operations. Managing director Adams and his counterpart at the LNG Company were suspended late in 1989, apparently for refusing to accept government appointees to the LNG Company. In April 1990, Thomas John took over as managing director.

Thus the NNPC entered the last decade of the century as a young company still trying to carve out an identity for itself, independent of political control, and still learning how to master the technological and commercial complexities of the oil industry. It did have a more developed diversification strategy than ever before in its history, however, and, for the moment, a government that was willing to dilute its holdings in the industry as the price for supporting the corporation's growth.

The Late 1990s and Beyond

Throughout most of the 1990s, Nigeria and NNPC dealt with civil unrest, political instability, border disputes, corruption at the highest levels, and poor governance. Even so, international oil companies looked to Nigeria as a lucrative investment opportunity related to upstream oil exploration. Especially attractive was the sedimentary basin of the Niger Delta, as well as the Anambra Basin, the Benue Trough, the Chad Basin, and the Benin Basin.

Although NNPC management had been promising changes for years, company efforts had been slow at best and many Nigerians looked at NNPC with disdain. New reforms, however, were on the horizon for the new millennium. After 16 years of military rule, Nigeria held democratic elections in 1999. Olusegun Obasanjo was elected president and immediately set out to reorganize the country's oil and gas sector. As part of his restructuring efforts, President Obasanjo placed a strong emphasis on natural gas development. At the time, most of the country's natural gas was being flared, a very wasteful and environmentally unfriendly process. As such, a mandate was set forth that called for the termination of gas flare, a focus on environmental cleanup, and the realization of economic gains from natural gas in both the import and export market so that gas revenues equaled oil revenues by 2010. Nigeria had secured a position as a significant exporter of natural gas through the Nigeria liquefied natural gas (LNG) Plant in Bonny by 2005. In December 2004, NNPC management set plans in motion to launch the West African Gas Pipeline, which would supply gas from Nigeria to West Africa including Ghana, Benin, and Togo.

In February 2005, the government set plans in motion to host a three-day public hearing in the capital city of Abuja. The hearing was designed to create changes in the oil industry that would bring about higher revenues and new jobs. In March of that year, the Hart Group was appointed to conduct a five-year audit of Nigeria's oil and gas operations. Another reform set forth was the hotly contested privatization of certain segments of the oil and gas industry. In 2003, the government began to deregulate fuel prices and announced that its four major oil refineries would be privatized. NNPC was slow to respond to this mandate, unsure of how privatization would affect its business.

Led by managing director Funsho Kupolokun, NNPC launched a series of job cuts in the early years of the new millennium. Massive layoffs began in 2003 and approximately 2,355 employees were let go in 2005. The company also made several key partnerships at this time. Working with Chevron Texaco and British Gas, NNPC developed a LNG project in the border town of Olokola. It was expected that the project would gross $57.4 billion in its lifetime. In February 2005, NNPC signed a $1 billion contract with Chevron Texaco Nigeria to construct the Floating, Production, Storage, and Offloading Vessel (FPSO) for the Agbami deep offshore oil field. The FPSO was expected to process 250,000 barrels per day of crude oil and 450 million standard cubic feet of gas per day.

Although NNPC looked to be on a positive path for the future, it continued to face issues related to civil unrest and corruption. Kupolokun faced a tough road ahead, but there were no doubts that NNPC would remain a fixture in Nigeria's oil and gas sector for years to come.

Principal Subsidiaries

Duke Oil Ltd.; Eleme Petrochemicals Company Ltd. (EPCL); Integrated Data Services Ltd. (IDSL); Kaduna Refining and Petrochemicals Company Ltd. (KRPC); National Engineering and Technical Company (NETCO); Nigerian Gas Company (NGC); Nigerian Petroleum Development Company Ltd. (NPDC); Pipelines and Products Marketing Company Ltd. (PPMC); Port Harcourt Refining and Petrochemicals Company Ltd. (PHRC); Warri Refining and Petrochemicals Company Ltd. (WRPC).

Principal Competitors

National Iranian Oil Company; Petróleos de Venezuela S.A.; Saudi Arabian Oil Company.

Further Reading

Ake, Claude, The Political Economy of Nigeria, London: Longman, 1985.

Mahtani, Dino, "Hopes Pinned on Offshore Development," Financial Times London, April 26, 2005.

"Nigerian Economy Is Expected to Gross US$57.4 Billion," Liquid Africa, January 18, 2005.

"Nigeria's Oil and Gas Sector Faces Overhaul," LPG World, May 18, 2005.

"NNPC Sacks Over 2,000 Employees," Weekly Petroleum Argus, January 3, 2005.

Oduniyi, Mike, "NNPC: Helping to Sustain Democracy," All Africa, June 1, 2005.

Onoh, J.K., The Nigerian Oil Economy, Beckenham: Croom Helm, 1983.

Pearson, Scott R., Petroleum and the Nigerian Economy, Stanford, Calif.: Stanford University Press, 1970.

—Graham Field

—update: Christina M. Stansell

Monday, July 5, 2010

Power Outage at the Murtala Muhammed Airport

Power outage throws VIP lounge into darkness
By Kelvin Osa- Okunbor 05/07/2010 00:00:00




The Presidential wing of the Murtala Muhammed Airport, Ikeja, Lagos, was thrown into darkness yesterday following power outage.

The wing is used by the president, vice president, governors senior government officials and past leaders when passing through the airport.

Doors of offices were left ajar for fresh air to come in as the workers battled with intense heat.

The generator at the power house near the lounge was not of help because it has become obsolete.

The engineers have been asking that it be changed for improved power supply.

Some sections of the Murtala Muhammed International Airport were also in darkness.

The staff quarters were not spared. Many residents were seen on their balconies fanning themselves with papers.

Sources said the generator was no longer, effective having been bought in the early eigties.

Assistant Secretary-General of the Airline Operators of Nigeria (AON), Mohammed Tukur has advised the Federal Government to privatise the Federal Airports Authorities of Nigeria (FAAN) for effective running of the airport.

Tukur spoke against the background of the parlous state of facilities at airports nationwide.

He said: "We as airline operators are just managing the facilities at airports across the country, the committee has written its report and submitted to government on areas it needs to fix obvious gaps in infrastructure.

"If you look at FAAN, everything is wrong, there is need for action, and the way to act now is for government to carry out a surgical analysis of the airports authority, then look at the personnel, then go ahead and privatise.

Another way is to examine individual airports, and give out to concessionaires to manage. A situation in which government continues to dole out money to fix the airport is not acceptable, because the money will be embezzled by those in the system.

People will continue to canvass release of funds to fix the airports so that they can misappropriate the funds, those who are saying do not give the airports out to private managers are unfair in their thinking, their understanding of airport management is not in line with contemporary technology, government is not training enough personnel in the appropriate areas, we are still hanging on trivial issues.

"The truth of the matter is that government should start looking at the personnel of FAAN, those who are trainable, and those who are too rigid or old to get along should be eased out and paid off."

EFCC Arrests Briton

EFCC arrests Briton for ‘duping’ Fashanu of over N84m

By Yusuf Alli 05/07/2010 00:00:00




The Economic and Financial Crimes Commission (EFCC) has arrested a British businessman, David Littlechild, for allegedly swindling Nigerian Sports Ambassador, Mr John Fashanu, of over N84million.

The Briton is said to be the Managing Director of Business Mart Limited in Ikeja, Lagos.

Source said the suspect was arrested last Thursday in Lagos by a team of operatives.

Littlechild’s arrest followed a petition to the anti-graft commission by Fashanu in 2006.

It was learnt the suspect, who is regarded as highly connected to some political office holders, had been evading investigation.

But following a fresh alarm by Fashanu, the EFCC Chairman, Mrs. Farida Waziri, ordered a revisit of the case.

An EFCC source said: "We have been on the trail of the suspect for a while. We succeeded in arresting him last Thursday.

"Our operatives picked up David Littlechild for allegedly duping Fashanu of 30,000 pounds sterling (about N69,300,000) and another $100,000 (over N15million).

"Investigations so far confirmed that the suspect, who is being detained in Lagos, obtained the funds under false pretences.

"It was also discovered that the suspect has been convicted four times in the UK for various offences.

"Since his arrest, we have asked him to respond to issues raised in Fashanu’s petition," the source said.

The Head of Media and Publicity of the EFCC, Mr. Femi Babafemi, confirmed the arrest of the suspect.

He, declined giving further details because investigation is still on.

Jonathan’s Camp Woos North’s Minorities

2011: Jonathan’s camp woos North’s minorities
By Yusuf Alli and Chris Oji 05/07/2010 01:10:00



The President’s supporters are strategising to ensure he runs in next year’s election, despite the zoning hurdle.

Some of them, including a former Minister of Information, Chief Edwin Clark, and the National Chairman of the People's Democratic Party (PDP), Dr. Okwesilieze Nwodo, on Friday held a secret meeting with key minority leaders from the North.

Pioneer PDP chair, Solomon Lar called said a conference on zoning -the hurdle faced by the President -was on the way.

South-East governors said they would back a candidate with a good programme. None of them will run, they said.

The Abuja meeting was a move to break the ranks of elders and governors of the North who are perceived to be hell-bent on stopping Jonathan from contesting next year.

It was gathered that the South-South leaders may form a new power alliance (Congress for Equity and Change) with Northern minorities.

The meeting was held at Clark’s Plot 1280, Asokoro District, Abuja.

The session was attended by leaders from the North-East, North-Central and South-South.

At the meeting were a former President of the Senate, Chief Ameh Ebute; ex-NADECO chieftain Air Commodore Dan Suleiman, Bala Takaya, Nigeria’s former High Commissioner to the UK Gen. Halidu Hananiya; Senator Silas Janfa; Adamawa State PDP chairman; and ex-Deputy Speaker of the House of Representatives Babangida Nguroje.

Others from the South-South are a former Commissioner in Bayelsa State, Chief Whiskey Ayakeme; Dr. Michael Ogberebo; a former Presidential Adviser on National Assembly Matters, Dr. Esther Uduehi; and a former President of the National Council of Women Societies (NCWS).

A source, who spoke in confidence, said: "One of the objectives of the meeting was to break the ranks of the North and secure support for Jonathan in about six to seven out of the 19 Northern states. There is already an assumption that the 17 states in the South-West, South-East and South-South will vote massively for Jonathan at the PDP National Convention.

"All these meetings are in line with the countdown to the presidential primary of the PDP. We are all strategising."

Another source added that Nwodo told the meeting that "Jonathan is qualified to participate in the PDP presidential primary and 2011 poll, provided he follows due process".

He also quoted the PDP National Chairman as saying: "PDP will ensure that due process is followed in its primaries to avoid our members going to other parties to contest."

On zoning, the source said Nwodo recalled that the formula was "only used in the 1999 and 2003 polls".

The PDP chairman unfolded plans to conduct online registration of new members.

Nwodo said: "All the state branches of the PDP will be given a bank account where every intending member will pay N100 a month.

"With the bank teller, you will become automatic member of the PDP. The only way to control the congress/convention delegates from being hijacked is to ensure that all of them are registered online."

South East governors yesterday resolved that they will not contest for President and Vice president in 2011 but refused to take a definite stand on whether they would support President Goodluck Jonathan for presidency or not.

They said they would rather support a candidate with the best programme that would address the "marginalisation of the South-East" as well as correct "the political imbalance" in the country.

"On the matter of national politics, the governors have resolved in the interest of the zone to stand and work together, irrespective of party affiliations. In that vein, the governors resolved that none of them will vie for the post of the president or vice president of the nation in 2011. We will support for presidency a candidate with the best programme that will address the marginalisation of the South-East zone and political imbalance in Nigeria," the governors said in a communiqué issued after their meeting in Enugu last night.

The governors, who met under the aegis of Forum of South-East Governors, also resolved to jointly wage a war against kidnapping, which has become a major security problem in the zone.

"We have resolved to match the perpetrators in the zone with equal force," the governors declared in the communique read by Governor Peter Obi of Anambra State.

The security measures adopted by the governors were not disclosed, but they specified some punitive measures to curtail the menace, which they described as disturbing.

These include that:

•all property owners in the zone are advised to ensure that their properties are not used to facilitate kidnapping as any such properties would be seized by government and the Certificate of Occupancy revoked,

•all traditional rulers and presidents-general of town unions in the zone are hereby warned that they would be held responsible for criminal acts in their communities, which occurrence would lead to withdrawal of certificate of recognition of traditional rulers or removal of the town union president-general in addition to prosecution; and that

•leaders of various market unions and motor parks will also be held responsible for what happens within their domains and finally parents and families are warned to counsel their wards to desist from any acts capable of associating them with cases of kidnap."

All the five governors were present at the meeting, which lasted for four hours.

NFF Sacks Lulu, Ogunjobi, Uchegbulam

NFF sacks Lulu, Ogunjobi, Uchegbulam
By Andrew Abah 05/07/2010 00:30:00



The impasse in Nigeria football took another dimension Sunday as the board of the Nigeria Football Federation (NFF) impeached its President, Sani Lulu, Vice-President, Amanze Uchegbulam and Chairman, Technical Committee,Taiwo Ogunjobi.

The NFF board met in the early hours of Sunday at the NICON Luxury Hotel, Abuja, at the instance of the Federal Government.

The action of the NFF’s executive committe was derived from Act 34 (m) of the 2010 Nigeria Football Federation 2010 statutes. All members of the boards were in attendance except the three impeached executives. In place of Lulu, Aminu Magari was elected as Acting-President while Obinna Ogba replaced Uchegbulam as Vice-President.

FIFA has threatened to expel Nigeria from world football unless the Nigerian President Goodluck Jonathan lifts the two-year ban imposed on the national teams.

FIFA rules however, prohibits government’s intervention in its members' affairs.

The NFF said the three sacked members were given the boot "to tender an unresolved apology" to all Nigerians over the team's performance in South Africa.

The NFF also promised "to take urgent steps to address the maladministration of football in the country".

FIFA has imposed Monday deadline for the Nigerian government to reverse its decision after writing to President Jonathan.

The country's House of Representatives has passed a resolution asking the Nigerian president to reverse his order, fearing sanctions.

Jonathan's government announced on Wednesday that the NFF would be dissolved and an interim board put in place.


"President Goodluck Jonathan has directed that Nigeria withdraws from international competitions for two years to enable the country to put its house in order," special presidential adviser, Ima Niboro, had said.

However, FIFA rules clearly state that national associations can be expelled if governments are seen to be interfering with the way they operate.

"FIFA has sent a letter to the Nigeria Football Federation (NFF) indicating that the government of Nigeria has until Monday 6pm to reverse its direction to withdraw Nigeria's participation from all FIFA and CAF competitions for the next two years," said FIFA communications director Nicolas Maingot on Friday.

"Also the management committee set up by the Nigerian government will not be recognised by FIFA."

If Nigeria is suspended, the country cannot participate in competitive matches or club games in African competitions.

"A suspension goes beyond the suspension of the national teams," added Maingot. "It also freezes financial help and no referees can participate in international competition."

FIFA executive committee member and former Nigeria government minister Dr Amos Adamu will be in the country on Monday "for a last mediation attempt."

The governing body's president, Sepp Blatter had already warned French President Nicolas Sarkozy of possible sanctions after he pledged to personally lead an investigation into France's acrimonious World Cup campaign.