Tullow Oil plc has issued this statement to summarise recent operational activities and to provide trading guidance in respect of the financial year to 31 December 2016.
This is in advance of the Group’s Full Year Results, which are scheduled for release on Wednesday 8 February 2017. The information contained herein has not been audited and may be subject to further review and amendment.
Aidan Heavey, Chief Executive said:
“2016 was another tough year for the oil & gas sector and for Tullow. However, the Company showed exceptional resilience and strong operational performance to deliver TEN on time and on budget; to deal with the technical issues at Jubilee; make good progress in exploration and development in East Africa and begin the process of reducing our debt from free cash flow. Tullow is therefore now very well placed to take advantage of the opportunities that conditions in the sector offer. We took action early to deal with lower oil prices and we are now benefitting from the re-set and re-structured business that we created. Our US$900 million farm-down in Uganda this week is clear evidence of the commercial attractiveness of our East African portfolio and our ability to manage our assets according to the strategic and financial needs of the business.”
Tullow’s West Africa 2016 oil production was in line with recent guidance averaging 65 500 bpd. This includes 4600 bpd of production-equivalent payments received under Tullow’s Business Interruption insurance policy for the Jubilee field. In Europe, working interest gas production performed in line with expectations and full year net production averaged 6200 boe/d.
In 2017, West Africa working interest oil production, including production-equivalent insurance payments, is expected to average between 78 000 and 85 000 bpd. Europe working interest gas production is expected to average between 6000 and 7000 boe/d.
Full year 2016 gross production from the Jubilee field averaged 73 700 bpd (net: 26 200 bpd). Tullow has also received reimbursements for turret remediation costs and Jubilee production field losses in 2016 of approximately US$8 million (net) under the Hull and Machinery insurance policy and approximately US$72 million under Tullow’s corporate Business Interruption insurance cover which equates to 4600 bpd of net equivalent production.
The Jubilee turret remediation work is progressing as planned and the FPSO is expected to be spread-moored on its current heading by the end of January 2017. This will allow the tugs currently required to hold the vessel on a fixed heading to be removed, significantly reducing the complexity of the current operation. The capital costs associated with this and subsequent remediation works are expected to be covered by the Joint Venture Hull and Machinery insurance policy.
The next phase of the project will involve modifications to the turret systems for long-term spread-moored operations. In addition, the assessment of the optimum long-term heading continues, in order to determine if a rotation of the FPSO is required. Detailed planning for this continues with the JV Partners and the Ghanaian Government, with final decisions and approvals being sought in the first half of 2017, with work expected to be carried out in the second half of 2017. It is anticipated that a facility shutdown of up to 12 weeks may be required during 2017. However, significant work is ongoing to look at ways to optimise and reduce any shutdown period.
Tullow expects 2017 production from the Jubilee field to average 68 500 bpd (net: 24 300 bpd), assuming 12 weeks of shutdown associated with the next phase of remediation works. Tullow’s corporate Business Interruption insurance cover is expected to continue to payout in respect of lost production associated to the turret remediation works, and the equivalent average annualised net production is around 12 000 bpd, increasing Tullow’s effective net production to around 36 300 bpd in 2017.
Following first oil from TEN in August 2016, the oil production, gas compression/injection and water injection systems were commissioned and are now operational. In early January 2017, the capacity of the FPSO was successfully tested at an average rate of over 80 000 bpd during a 24 hour flow test.
Gross annualised working interest production in 2016 averaged 14 600 bpd (net: 6900 bpd), in line with latest guidance.
Production testing and initial results from the 11 wells indicate reserves estimates for both Ntomme and Enyenra to be in line with previously guided expectations. However, due to some issues with managing pressures in the Enyenra reservoir and because no new wells can be drilled until after the ITLOS ruling later this year, Tullow plans to manage the existing wells in a prudent and sustainable manner. As a result, Tullow expects production from TEN to be around 50 000 bpd (net: 23 600 bpd) in 2017, although work continues to consider ways to increase production in 2017.
Gas production from the TEN fields is currently being re-injected, with gas export expected to commence later in 2017.
Proceedings at ITLOS, with regard to the maritime border dispute between Ghana and Côte d’Ivoire continue, with oral hearings expected 6 - 17 February 2017, and a final ruling anticipated in the fourth quarter of 2017.
2016 West Africa net non-operated production was in line with expectations at 27 800 bpd. Lower oil prices have resulted in significantly lower levels of investment and 2017 net production is expected to be around 22 000 bpd. However, flexibility remains in the portfolio, with options to increase capital investment in 2017 and subsequent years to reduce the production decline in these mature assets.
Full year gas production from Europe averaged 6200 boe/d in 2016, in line with expectations. Tullow expects 2017 European gas production to be around 6500 boe/d.
A four-well exploration and appraisal programme commenced in mid-December in the South Lokichar Basin with the drilling of the Erut-1 well, located in the north of the basin, approximately 11 km north of the Etom field. The well is nearing completion, with a result expected shortly. The rig will then move to drill Amosing-6, a well targeting undrilled volumes, before moving to Ngamia-10, an appraisal well to the south of the Ngamia discovery. The planned final well in the programme is the Etete prospect, a structure approximately 2km south of the Etom field. This programme could be extended by up to four additional wells in 2017, depending upon the assessment of the results from the initial four wells.
Water injection trials have been successfully completed on the Amosing discovery in the South Lokichar Basin. Data collected shows the viability of water injection for development planning. A similar programme of water injection tests on the Ngamia discovery are scheduled to commence later this month.
Work continues on the Early Oil Pilot Scheme, full field development planning and the export pipeline.
On 9 January 2017, Tullow announced that it has agreed a substantial farm-down of its assets in Uganda to Total. Under the Sale and Purchase Agreement, Tullow has agreed to transfer 21.57% of its 33.33% interest in Exploration Areas 1, 1A, 2 and 3A in Uganda to Total for a total consideration of US$900 million. The farm-down leaves Tullow with an 11.76% interest in the upstream and pipeline, which will reduce to 10% when the Government of Uganda formally exercises its right to back-in.
The consideration is split into US$200 million in cash, consisting of US$100 million payable on completion of the transaction, US$50 million payable at FID and US$50 million payable at first oil. The remaining US$700 million is in deferred consideration and represents reimbursement by Total in cash of a proportion of Tullow’s past exploration and development costs. The deferred consideration will fund Tullow’s share of the development and pipeline costs as the Lake Albert Development reaches a series of key milestones. Completion of the transaction is subject to government approval, after which Tullow will cease to be an operator in Uganda.
This agreement will allow the Lake Albert Development to move ahead and increases the likelihood of FID around the end of 2017.
Tullow has continued to advance its operations in South America and plans are ongoing to drill the potential high impact Araku prospect (Tullow: 30%), offshore Suriname, in the second half of 2017. In Guyana, planning is ongoing to acquire 3D seismic data over the offshore Kanuku and Orinduik licences located updip of the Liza oil discovery.
The divestment of the Norway business is almost complete, with the sale of four licences to Statoil and eight licences to Aker BP ASA completed before year end 2016. A further three sales were executed in December 2016, which are expected to be completed in the first half of 2017.
Following the scheduled amortisation of RBL commitments in October 2016, the Group ended the year with available credit under the RBL facility of US$3.3 billion. At the end of 2016, Tullow had total facility headroom and free cash of US$1 billion and net debt of US$4.8 billion, which includes the US$300 million Convertible Bond offering in July 2016. The improvement in the year end net debt and liquidity position versus previous forecasts is largely due to the cashflow contribution from TEN and ongoing capex and cost management.
In 2016, Tullow expects to deliver revenue of c.US$1.3 billion, gross profit of c.US$0.5 billion and operating cash flow of c.US$0.7 billion. Due to the current low oil price and the impact of disposal and farm-down transactions, a number of accounting charges are forecast to be incurred in the 2016 income statement. These charges comprise a goodwill impairment of c.US$0.2 billion, a post-tax exploration write-off of c.$0.3 billion, a post-tax impairment charge of c.US$0.1 billion and an onerous service contract charge of c.$0.1 billion.
In 2016, Tullow’s oil and gas hedge programme contributed US$363 million to revenues, and as we look ahead to 2017, the hedging position continues to provide protection of future revenues and cashflows. The mark-to-market value at the end of December 2016 was US$91 million and Tullow will benefit in 2017 from approximately 60% of entitlement oil production hedged at an average floor price of around US$60/bbl on a pre-tax basis.
Capital expenditure will continue to be carefully controlled during 2017. The Group’s capital expenditure associated with operating activities is expected to reduce from US$0.9 billion in 2016 to US$0.5 billion in 2017. The 2017 total comprises Ghana Capex of c.US$90 million, West Africa non-operated Capex of c.US$30 million, Kenya pre-development expenditure of c.US$100 million and Exploration and Appraisal spend limited to c.US$125 million. Uganda expenditure of US$125 million will be offset by the Uganda farm-down deferred consideration.
Read the article online at: https://www.oilfieldtechnology.com/drilling-and-production/12012017/tullow-trading-statement-and-operational-update/