EXECUTIVE SUMMARY
Background
The Honourable Minister of Petroleum Resources, driven by the need to strengthen the institutions responsible for Petroleum Revenue Management, commissioned the Petroleum Revenue Special Task force (PRSTF) on 28 February 2012. The goal of the Task Force was to support the programme of the Federal Government of Nigeria in enhancing optimization, probity and accountability in the operations of the Petroleum Industry.
As part of this agenda and the issues arising from the various fiscal regimes existing in the sector, there arose an urgent need to establish the streams of revenue flows from the Petroleum sector to the Federal Republic of Nigeria and design systems and processes which would enhance the accountability of each agency or entity.
The assignment of the Special Task Force is contained in its Terms of Reference and covers the entire Petroleum Value Chain. Accordingly, the Task Force set out to confirm if existing systems, laws, processes and functions across the value chain provide reasonable assurance that revenues from the Petroleum Industry are captured, complete, recorded intact, properly accounted for and that revenue due is demanded and collected.
Terms of Reference
At the inauguration of the Petroleum Revenue Special Task Force, the following Terms of Reference (ToR) were communicated:
1. To work with consultants and experts to determine and verify all petroleum upstream and downstream revenues (taxes, royalties, etc) due and payable to Federal Government of Nigeria;
2. To take all necessary steps to collect all debts due and owing; to obtain agreements and enforce payment terms by all oil industry operators;
3. To design a cross debt matrix between all Agencies and Parastatals of the Ministry of Petroleum Resources;
4. To develop an automated platform to enable effective tracking, monitoring and online validation of income and debt drivers of all Parastatals and Agencies in the Federal Ministry of Petroleum Resources;
5. To work with world-class consultants to integrate systems and technology across the production chain to determine and monitor crude oil production and exports, ensuring at all times, the integrity of payments to the Federal Government of Nigeria; and
6. To submit monthly reports for ministerial review and further action.
Scope and Methodology
Since its inauguration, members of the PRSTF have approached the assignment with all the seriousness that it
deserves. In carrying out its ToR, one of the initial activities performed by the PRSTF was to obtain both written and verbal presentations from the various stakeholder groups within the Petroleum Industry. This was to enable the Task Force to understand the challenges faced and the type of reforms that are required. This was all carried out with a view to determining and optimising the nation’s revenue streams from all sectors within the industry.
The Task Force members also visited and reviewed selected agencies and operators, supported by the Consultants, for the period spanning 1 January 2005 to 31 December 2011 in line with the Statute of Limitations. Two workshops were also held to aid information gathering process with respect to key
issues of Metering and Measurement in the Oil & Gas Sector Value Chain, and Security in the Oil and Gas Sector.
Apart from several plenary meetings to receive briefings, analyse gathered information and deliberate on findings, the Task Force also operated through constituted two (2) ad-hoc subcommittees to conduct a detailed review of NNPC’s and DPR’s roles in petroleum revenue management. Five (5)standing subcommittees were also formed and conducted detailed assessments followed with recommendations in
specific areas relevant to the overall ToR. Specifically in pursuance of ToR 2, the Task Force through the Security and Enforcement Subcommittee also liaised with relevant agencies to validate the status of outstanding debts identified in the course of the forensic review, and to demand payments where deemed necessary.
Revenue Review and Debt Verification Findings
The Task Force in pursuance of ToR 1 and 2 conducted activities to determine and verify all Petroleum Upstream and Downstream Revenues due and payable to Nigeria; and took all necessary steps to collect all debts due and owing.
It was determined that the main petroleum revenues due to the national treasury in respect of oil and gas activities in Nigeria are:
Domestic Crude Oil Sales, Equity Crude Oil Sales, Gas Sales, Refined Petroleum Products sales, Profits from NNPC subsidiaries, Petroleum Profits Tax, Company Income Tax, Signature Bonus, Concession Rentals, Royalties from Oil and Gas, Gas Flare Penalties, and Miscellaneous Oil Revenues.
The Task Force’s key findings are presented below according to these revenue streams.
1. Proceeds from the sale of Domestic Crude Oil:
As at 31 December 2011, N843 million1 was due to the
Federation in respect of Domestic Crude Oil allocations. The amounts outstanding as at 31 December 2011 represent amounts due for the months of September 2011 to December 2011. In view of the 90-day credit period, the outstanding amount as at 31 December 2011 was not due for payment.
Federation in respect of Domestic Crude Oil allocations. The amounts outstanding as at 31 December 2011 represent amounts due for the months of September 2011 to December 2011. In view of the 90-day credit period, the outstanding amount as at 31 December 2011 was not due for payment.
The Task Force received representations from the NNPC and other relevant agencies on the Corporation’s practice of deducting amounts for subsidy-related expenses prior to remittance of these revenues. In the course of the Task Force’s work, we did not receive sufficient justification for the practice which does not accord with the law, with particular reference to the Constitution.
Our review of the records received for 2002 to 2011 showed an inconsistent pattern in the implementation of the policy to allocate 445,000bpd allocation to NNPC, with variances found for the ten years reviewed.
The Task Force also compared the average price per barrel payable by NNPC for Domestic Crude with the average weekly prices for Nigeria Bonny Light, Forcados, obtained from the Energy Information Administration (EIA). The review revealed that over a 10 year period (2002 – 2011), the State may have been short paid by an estimated sum of US$ 5 billion, although it was understood from discussions with
NNPC officials that the pricing of domestic crude oil was based on international prices. Enquiries from NNPC revealed that up until October 2003, NNPC was granted fixed price regimes which explain the wide disparity in prices in the earlier years.
The Task Force also compared the average price per barrel payable by NNPC for Domestic Crude with the average weekly prices for Nigeria Bonny Light, Forcados, obtained from the Energy Information Administration (EIA). The review revealed that over a 10 year period (2002 – 2011), the State may have been short paid by an estimated sum of US$ 5 billion, although it was understood from discussions with
NNPC officials that the pricing of domestic crude oil was based on international prices. Enquiries from NNPC revealed that up until October 2003, NNPC was granted fixed price regimes which explain the wide disparity in prices in the earlier years.
The Task Force found that the exchange rates used in arriving at the Naira equivalent of the amounts payable
differed from the CBN rates for six (6) of the ten (10) years reviewed. The potential underpayment of amounts payable to the Federation Account over the 10- year period is estimated at N86.6 billion. Also, the Task Force’s review of the domestic crude utilisation showed that the percentage not refined in- country ranged from between 50% to 88% over the 10 year period.
2. Proceeds from Equity Crude Oil Sales:
Equity Crude represents government’s share of crude oil production (excluding domestic crude) obtained mainly from three (3) arrangements: Joint Operating Agreements (JOA) with IOCs, Production Sharing Contracts (PSC) and Service Contracts. Equity Crude Oil proceeds are remitted into the Federation account as export proceeds, DPR accounts as Royalties and FIRS accounts as Petroleum Profit Tax.
The Task Force observed that there is no single point accountability for the income and expenditure streams of upstream petroleum operations, compounded by the current structure of NNPC such as multiple roles executed through NAPIMS and its COMD.
A decline was also observed in national investments that would increase the nation’s proven reserves. Accordingly, despite the increase in crude oil production in Nigeria over the years, the nation’s entitlement has decreased as a result of various alternative funding arrangements for its upstream investments.
The Task Force found that legislation governing the industry and agreements with third parties are outdated, do not reflect current economic or legal realities; or include ambiguous clauses. Also, there are some provisions within the legislation that could significantly improve government’s revenue that the government is yet to take advantage of. Examples include a provision to ensure that the share of the Government of the Federation in the additional revenue shall be adjusted under the Production Sharing Contracts if the
price of crude oil at any time exceeds $20 per barrel; and the requirement for a periodic review of provisions in specified time frames.
It was also observed that some traders lifted crude oil although they were not listed on the approved master list of customers who had a valid contract and were selected through an annual bidding process. The Task Force research also found that quite a number of traders did not demonstrate renowned expertise in the business of crude oil trading.
Furthermore, the Task Force found that the use of crude oil traders was contrary to the global trend wherein national oil companies develop their own trading arms, such as the various NNPC trading subsidiaries which currently have limited capacity. The Task Force identified various concerns in this area with Nigeria being the world’s only major oil producer that sells 100 percent of its crude to private commodities traders, rather than directly to refineries.
Various submissions to the Task Force demonstrated the potential for lost margins to middlemen, manipulation of pricing, suboptimal returns and market fraud as emanating from this policy and practice.
A review of NAPIMS’s audited financial statements as at 31 December 2009 showed that Joint Venture cash calls payable was N459.568billion. Since 2006, government has not allocated enough funds to cover these amounts and NNPC has entered into a range of borrowing arrangements referred to as Alternative Financing Arrangements with the costs of financing this debt (estimated at around 8%) continuously mounting. This cycle will continue to increase in the coming years unless a systemic solution is found.
As JV partners there is a need for the effective management and oversight of oil companies’ operating costs which affects revenues accruable to Nigeria. There is also a clear training, technology and human capacity gap between NAPIMS staff and their counterparts in the private oil and gas sector.
3. Proceeds from the Sale of the National Entitlement (Gas):
The Task Force aided by the Consultants identified a total of N137.572 billion ($946.878 million) due to the Federation from SNEPCO representing the proceeds of gas sales from the Bonga oil field; according to the NNPC (NAPIMS) Financial Statements for the year ended 31 December 2009.
For Liquefied Natural Gas, the price observed at which the feedstock gas is sold to NLNG seems too generous, compared to prices obtainable on the international market. The estimated cumulative of the deficit between value obtainable on the international market and what is currently being obtained from NLNG, over the 10 year period, amounts to approximately US$29 billion.
4. Proceeds from Sale of Petroleum Products:
From the Task Force’s review, NNPC is owed N27billion including current debt, total overdue, disputed debt and total debt outstanding, by the major marketers of petroleum products. We also found that amounts payable to suppliers of petroleum products, as at 31 December 2011 amounts to approximately US$3.6 billion, of which US$2.7 billion represents amounts outstanding for over 365 days. The Task Force also observed that pipeline product loss has steadily increased over the years.
5. NNPC and Subsidiaries:
From review of the latest available audited financial statements (2009) it was noted that NNPC has sixteen (16) subsidiaries. The financial performance of the Corporation and its subsidiaries in 2009 shows the Group had a deficit of approximately N298billion for the period. Various reviews conducted by the Task Force showed that the NNPC does not receive the required capital to grow its assets or meet operating costs. NNPC has therefore increasingly relied on the FGN for lines of credit, and deduction of oil revenue due
to the Federation Account. In our review, the legal basis for this practice was unclear.
to the Federation Account. In our review, the legal basis for this practice was unclear.
6. Signature Bonus:
The Task Force found that discretionary decision-making in the award of oil blocks can result in revenue losses for Nigeria. Our review also showed that the management of past bid rounds has resulted in lower demand and fewer qualified bidders, uncompleted deals weakened government returns, and lower development of acreage.
The DPR provided the task force with information indicating that 67 licenses were awarded between 1 January 2005 and 31 December 2011; with an outstanding balance of $566 million unpaid in signature bonuses. For the 7 discretionary allocations reviewed, the Task Force found $183million outstanding and due to the nation’s treasury. We were however informed that of the total $749m outstanding in
signature bonuses, $321m was legally disputed.
signature bonuses, $321m was legally disputed.
7. Concession Rentals:
The Task Force found that $2.9million represents outstanding amounts to be collected by the DPR from the various concessionaires. However, we also observed inconsistencies in records provided by DPR in respect of information and schedules regarding the list of concessions.
8. Royalties (Crude Oil and Gas):
The Task Force found that $3.027billion was outstanding from the operators for crude oil royalties as at 31 December 2011 per the DPR’s records. Of this amount, the DPR had stipulated that ADDAX is liable to pay $1.5billion royalties under the 2003 fiscal regime and there is currently a dispute between Addax and NNPC on the one hand, and the DPR on the other. In the course of the review, the Task Force also
encountered differences in records of payments made to the CBN vis-a-vis DPR records, and lack of independent gas production and sales data.
encountered differences in records of payments made to the CBN vis-a-vis DPR records, and lack of independent gas production and sales data.
9. Gas Flare Penalties:
The Task Force found that the DPR is currently unable to independently track and measure gas volumes produced and flared and depends largely on the information provided by the operators. We also observed that the periodic reconciliation meetings with the operators to address the gas flare volumes were delayed with only 6 completed of 36 at the time of our review.
The total revenue from gas flaring during the review period was $175million with the balance outstanding as unpaid was approximately $58million indicating that $115million had been received by the DPR. We however reviewed payments received by the CBN in respect of gas flare penalties. However a review of CBN records showed that $137million was received between 1 January 2005 and 31 December
2011. The DPR was not able to reconcile the $115 million to the $137million.
Lastly, operators have not compiled with the recent Ministerial directive signed on 15 August 2011 increasing the gas penalty fee from N10.00 to $3.50. The operators have continued to flare gas at the rate of N10 and records at the DPR reveal that none of the companies have paid any gas penalty fee in 2012.
10. Miscellaneous Oil Revenues:
The Task Force was unable to obtain a comprehensive miscellaneous oil revenue schedule from the officials of the DPR, although a review of CBN’s records provided some information albeit with unexplained variances. The amounts due in respect of the various fees relating to the miscellaneous oil revenues are also not reflective of the current economic realities.
Revenue Losses in the Nigerian Petroleum Industry
The Task Force identified sources of revenue losses in the industry, with a view to identify opportunity areas for major reform in boosting resources obtainable from the sector for national development. These include the following.
1. Crude Oil Theft and Associated Revenue Losses:
Hydrocarbon theft was found by the Task Force as being a major and chronic source of revenue loss to Nigeria. Theft of crude oil and refined petroleum products may be reaching emergency levels in Nigeria.
The Task Force observed various estimates by International Oil Companies and Government officials of the scale and volume of crude theft which ranged from 6 to 30 percent of production. While the Task Force does not endorse any of the numbers it received, we note that it could actually be as high as 250,000 barrels per day closer to 10% of daily productions amounting to as high as N1 trillion annually. This issue therefore requires immediate attention.
2. Lost Refined Products and Associated Revenue
Losses
The Task Force did not receive comprehensive figures documenting volumes of refined products stolen or spilled. NNPC reports that thieves stole 3.2 million metric tons of products from its pipeline network between 2001 and 2010 and that about 40 percent of products currently channelled through pipelines are lost to theft and sabotage.
PPMC also recorded 4,468 product pipeline breaks in 2011, 98 percent of them from sabotage; and values the products stolen from its pipeline network between 2001 and 2010 at N178 billion.
3. NNPC Withholdings for Costs Associated With Theft
and Sabotage
NNPC withholds oil revenues from the Federation Account to cover costs associated with theft and pipeline sabotage.
4. Pioneer Status granted to Indigenous Companies
The Task Force was informed that at least five companies: Allied Energy, Midwestern Oil & Gas, Brittania Oil Nigeria Limited, Suntrust Oil Company Nigeria Limited; and Niger Delta Petroleum Resources Limited2 have been granted pioneer status by the Nigerian Investment Promotion Commission (with others pending or undetected) for their exploration and production activities.
The Task Force finds that the granting of pioneer status to oil operators for an activity that is well established for over 40 years inappropriate. The loss of revenue from the grant of pioneer status to oil operators is an avoidable loss and it is recommended that any such further consideration be stopped forthwith and the current ones set aside and or revoked.
1.Collateral Social Costs of Theft:
The Task Force also found that certain social costs emanated from crude oil theft and considered them important and requiring urgent attention. These include environmental pollution and its socioeconomic impacts, armed piracy, and lost investment in the sector leading to revenue losses.
Debt Collection
Based on the detailed review of outstanding debts owed to the Federation, the Task Force determined outstanding amounts for royalties, signature bonuses and concession rentals. Pursuant to an initial understanding of ToR 2 of the PRSTF, relevant government agencies were invited to assist in a debt collection drive, and invitation and demand letters were sent to over 47 oil companies allegedly indebted to the nation. We have recommended that government pursue debts further in any manner deemed appropriate.
However during the debt reconciliation exercise, the sum of USD$5,830,261 was paid into the treasury of Government with evidence of payment, while several companies made undertakings to pay at later dates.
However during the debt reconciliation exercise, the sum of USD$5,830,261 was paid into the treasury of Government with evidence of payment, while several companies made undertakings to pay at later dates.
Automation of the Nigerian Petroleum Industry
The Task Force identified Information Technology and
business automation gaps, by carrying out Current Position Assessments of the stakeholders within the Oil and Gas production value chain, including government regulatory parastatals. The assessment scope covered three broad categories namely Core Business Systems, Reporting Capabilities and Automation Capabilities of these entities.
business automation gaps, by carrying out Current Position Assessments of the stakeholders within the Oil and Gas production value chain, including government regulatory parastatals. The assessment scope covered three broad categories namely Core Business Systems, Reporting Capabilities and Automation Capabilities of these entities.
Our findings showed that there were evident automation gaps in the oil and gas value chain specifically in key agencies under the Ministry of Petroleum Resources/ Department of Petroleum Resources that are vested with the mandate to produce Oil and Gas, licence, keep and update records, supervise petroleum industry operations and ensure payment of rent and royalties. Additionally, the PRSTF reviewed the state of metering and measurement in Nigeria’s oil and gas value chain vis-a-vis best practices. The challenges identified with the current metering and measurement regime can be summarised as a lack of adequate vision and ownership required to articulate and drive a cohesive implementation of IT and Automation in MPR and DPR.
The Task Force identified the following specific challenges with the metering and measurement regime:
• Dependence on manual data gathering processes
• Low level infrastructure at remote locations
• Lack of regular and systemic well testing
• Inadequate data and IT infrastructure among industry players
• Inadequate MIS reporting and dashboard capabilities in existing systems
• Disparate systems with differing data, nomenclature among operators
• Diverse data requirements from Government agencies
• Multiple and strong stakeholders with divergent interests
The Task Force also found inconsistent oil and gas data across the petroleum industry. These inconsistencies in information were sighted across the major agencies and parastatals of the MPR as well as with the oil and gas operators themselves.
Recommendations
In order to address the findings and issues above, the Task Force has developed the following recommendations which Government should implement to address the issues identified and their root causes.
1. Strategic Management Recommendations
From a strategic viewpoint of the Task Force’s review and the findings discussed above, the Task Force recommends the following:
• Set up a process, independent of NNPC, to review the use of oil traders and NNPC’s system for selling crude, on grounds of value for money and probity.
• Undertake a strategic review of all NNPC subsidiaries before the PIB passes, with a view to privatizing, repositioning or scrapping non-performing, redundant or irrelevant business units.
• Require a full public report by NNPC of the amount,cost and terms of all cash call debts; improve reporting of this information to the National Assembly as part of the annual budget and oversight process.
• Pass an oil sector transparency law that requires all oil companies active in Nigeria to report all payments, costs and earnings for each license or transaction, and to publish all contracts and licenses.
• Create a special, properly-trained Oil and Gas Sector Financial Crimes Unit for law enforcement.
• Appoint a new NEITI Board, now long overdue. Members should be sector experts with a commitment
to transparency, and civil society should appoint independent representatives.
• Establish an embedded and independent office of transformation for the sector with a fixed term and specific mandate to carry through recommendations and transformational reforms accepted by government.
• Implement an aggressive debt collection process for outstanding signature bonus payments; revoke blocks from non-paying firms; sanction those agencies that failed to collect.
• Conduct an independent process audit of all upstream cost control rules and mechanisms, including the use of cross-country price benchmarking.
• Amend the 1984 Special Tribunal (Miscellaneous Offenses) Act to strengthen the legal framework for oil theft and other sector crimes.
• Arrest and prosecute perpetrators and financiers of illegal bunkering rings.
2. Production
• Production data for fiscal purposes should be obtained at the flow stations where crude oil is stabilised and
not at the terminals as is currently the practice.
3. Domestic Crude Sales
• No deductions should be made from the amounts payable to the Federation Account.
• Domestic crude oil should be sold at international competitive prices.
• FGN should block leakages in the conversion to finished goods process of NNPC.
• There should be full compliance by NNPC with prevailing CBN exchange rates for remittance of crude oil proceeds.
• The Federal Government should revisit the Domestic Crude Oil Business Model
4. Equity Crude Oil Sales
• Restructure NNPC for single point accountability for Petroleum Revenues
• National investment in the oil and gas upstream sector must be managed from a strategic focal point
• Ensure full compliance of all agencies and companies with existing legislation
• Regularise Crude Oil Lifting Under Contract
• Ensure open competitive selection process for crude oil sales
• Review the nominations process for all the Joint Ventures
• Ensure and institute proper review of all draft contractual agreements
• Adequate funding of the Federation’s investment obligations
• Create standard terms and conditions and uniform terms of contract agreements
• Proper and realistic budgets and approvals should be prepared annually
• Capacity Building should be embarked upon for NAPIMS in terms of optimal number and appropriate
skills and training level of staff
• Ensure uniformity of the realisable prices used by all parties
• Carry out adequate review of the purchase or lease option for production equipment
• Ensure and institute proper review of all draft contractual agreements
• Adequate funding of the Federation’s investment obligations
• Create standard terms and conditions and uniform terms of contract agreements
• Proper and realistic budgets and approvals should be prepared annually
• Capacity Building should be embarked upon for NAPIMS in terms of optimal number and appropriate
skills and training level of staff
• Ensure uniformity of the realisable prices used by all parties
• Carry out adequate review of the purchase or lease option for production equipment
5. Sale of the National Entitlement (Gas)
• Draw up master agreements for the development of all potential gas reserves in Nigeria
• FGN should ensure that written consents exist for gas for all assets
• FGN should intensify efforts to get the other LNG projects up and running
• FGN to carry out a comprehensive review of its NGL/LPG entitlements under the Agip and Shell Joint
Ventures
6. Signature Bonus
• The FGN should expedite action with respect to the blocks in dispute in order to ensure that the $321million outstanding is collected.
• DPR should take further actions against the concessionaires that are yet to pay the amounts due ($167million) within the remit of the law.
• Proper record keeping should be enforced at the DPR
7. Concession Rentals
• DPR should take action and enforce collections of the amounts due of $2.9million within the remit of the law.
• The DPR should put in place measures to ensure consistency and accuracy of custodial information
relating to oil and gas concessions
8. Royalties (Crude Oil and Gas)
• DPR should take action and enforce collections of the amounts due of $3.027billion from relevant operators within the remit of the law.
• DPR should make a demand for the outstanding Addax/NNPC Royalties payments of approximately
$1.5billion on behalf of the Federal Republic of Nigeria and the consequences of default should immediately
be visited on the contract and the relevant parties.
• DPR should instruct the CBN and operators to ensure the proper description of all revenue remittances in
order to facilitate easy reconciliation.
• DPR should independently track and record gas production and sales data
• DPR should ensure that all reconciliation process with all the outstanding gas producing companies is
concluded before the beginning of the next fiscal year.
9. Gas Flare Penalties
• DPR should independently track and record gas flare volumes
• The reconciliation process should be expedited for all operators to ensure timely collection of the gas flare penalty amounts due.
• DPR should take action and enforce collections of amounts due as gas flare penalties within the remit of the law.
• Enforce the new gas flare penalty directive as a disincentive to gas flaring.
• The FGN should put more effort in enforcing a zero gas flare policy by the beginning of the next fiscal year.
10. Miscellaneous Oil Revenues
• The DPR should employ the use of proper IT systems and databases to keep its records and ensure consistency and integrity of information across the organisation.
• The Fee and Licensing regimes for operating in the Oil and gas sector should be reviewed to reflect the current economic realities in the Oil and Gas industry
11. Removing the Source and Outlets of Revenue Losses
• Explore Fingerprinting of Nigeria Oil to enabletracking.
• Establishment of a transparent whistle blowing and information portal as an independent and transparent
repository of information on petroleum revenue losses, sabotage, and illegal activity.
• Implement a deliberate policy on market ban of participants in crude oil theft
• The Fiscal Responsibility Act 2007 should be amended to criminalize withholding payment of petroleum revenue after due date and assessment and a notice of demand.
12. Automation of the Nigerian Petroleum Industry
1. Department of Petroleum Resources
• The DPR should work with Galaxy Backbone and competent consultants to review on-going projects,
NDR and NPMS, and also develop a strategic IT blueprint for the organization.
• DPR and MPR should commence the implementation of a portal that aggregates and presents in real time all relevant information about the operations and performance of the oil and gas industry.
• An ERP Solution should be put in place to capture and automate the identified backend processes in DPR.
• DPR, based on its mandate should build a Data Warehouse which would serve as a hub for gathering vital data about the industry and disseminating reports in various formats to government stakeholders. A framework and implementation roadmap to full automation of measurement and metering should be developed in a collective effort involving DPR and theoperators with oversight from MPR.
2. Nigerian National Petroleum Corporation
• The implementation of SAP should be expedited to fully automate key processes especially relating to
revenue generation, processes feeding and pulling data to external parties.
• The NNPC’s culture, end user work ethics and employee resistance to change all need to be
managed extensively for the SAP implementation to be a full success.
• The SAP implementation should be independently monitored from the Ministry to track and ensure that
the strategic objectives are met.
3. Central Bank of Nigeria
• A quick win solution would be to study and automate the NXP forms with a view to track shipments and track repatriation of export proceeds.
• The existing CBN systems should be interfaced with other systems in the various relevant agencies in order to provide an overview of all revenue reporting and enable timely reconciliation between organizations.
1. Nigeria Customs Services (NCS)
• The existing NCS system should be integrated with other systems in the various relevant agencies in order to provide an overview of all revenue reporting and enable timely reconciliation between organizations.
1. Full automation of the Petroleum Industry
The PRSTF has recommended a way forward for the full automation of the Petroleum Industry. Key features of the proposed metering and measurement regime in particular are shown below.
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