SEVEN ENERGY FULL YEAR RESULTS - 2014 30 April 2015 Presentation - - PowerPoint PPT Presentation

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SEVEN ENERGY FULL YEAR RESULTS - 2014 30 April 2015 Presentation - - PowerPoint PPT Presentation

SEVEN ENERGY FULL YEAR RESULTS - 2014 30 April 2015 Presentation team Phillip Ihenacho Co-founder of Amaya Capital Partners, an early investor and active supporter of Seven Energy Chief Executive Officer Established and ran


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SLIDE 1

SEVEN ENERGY

FULL YEAR RESULTS - 2014

30 April 2015

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SLIDE 2

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Phillip Ihenacho

Chief Executive Officer

  • Co-founder of Amaya Capital Partners, an early investor and active supporter of Seven Energy
  • Established and ran Afrinvest for over 10 years
  • Former chairman of the Aureos West Africa Fund and worked with McKinsey & Co
  • BA in History from Yale University (US) and a JD from Harvard Law School (US)

Bruce Burrows

Chief Financial Officer

  • Joined Seven Energy in October 2011
  • Former finance director of JKX Oil & Gas for 14 years
  • Previously worked for Ernst and Young in various positions in London (UK) and Wellington (New Zealand)
  • BSc Honours from Canterbury University (New Zealand)
  • Member of the Institute of Chartered Accountants of New Zealand

Presentation team

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This announcement is for information purposes only and does not constitute an offer to sell or the solicitation of an offer to buy any security and shall not constitute an offer, solicitation or sale in the United States or Nigeria or in any jurisdiction in which, or to any persons to whom, such offering, solicitation or sale would be unlawful. The information contained in this announcement has not been audited by independent auditors or other third parties and is based on internal records and reporting systems. Certain statements in this report regarding our prospects, plans, financial position and business strategy may constitute forward-looking statements. Forward-looking statements generally can be identified by the use of forward-looking terminology such as “may”, “expect”, “intend”, “estimate”, “anticipate”, “plan”, “foresee”, “believe” or “continue” or the negative of these terms. All forward-looking statements, including discussions of strategy, plans, objectives, goals and future events or performance, involve risks and uncertainties. While we believe these statements to be reasonable, they are merely estimates or predictions and cannot be relied upon. We cannot assure you that future results will be achieved. Factors, risks and uncertainties that may cause actual outcomes and results to be materially different from those indicated, expressed, projected

  • r implied in the forward-looking statements used in this report include, among others:
  • the concentration of our primary reserves and resources in one geographic region pursuant to one agreement, the Strategic Alliance Agreement;
  • allegations that negatively portray our business, operations and assets, including but not limited to the Strategic Alliance Agreement, our interest in the OMLs and

relationships with third-parties;

  • a failure to agree upon the interpretation or application of certain contractual terms with our contractual counterparties with respect to the Strategic Alliance

Agreement;

  • logistical and operational difficulties associated with operating in Nigeria;
  • changes in governmental regulation, including regulatory changes affecting the availability of permits, and governmental actions that may affect operations or our

planned expansion;

  • the exposure to increased market risk and uncertainty as a result of operating in an emerging market;
  • the inability to obtain funds to maintain our ongoing operations, grow our business and complete planned projects;
  • delays, disruptions and disputes with third-party operators, partners and other project participants;
  • limited growth in Nigerian domestic demand for gas;
  • price fluctuations in oil, gas and refined products markets and related fluctuations in demand for such products;

This list of important factors is not exhaustive. When relying on forward-looking statements, you should carefully consider the foregoing factors and other uncertainties and events, especially in light of the political, economic, social, and legal environment in which we operate. Such forward-looking statements speak only as of the date on which they are made. Accordingly, we do not undertake any obligation to update or revise any of them, whether as a result of new information, future events or otherwise. We do not make any representation, warranty or prediction that the results anticipated by such forward-looking statements will be achieved, and such forward-looking statements represent, in each case, only one of many possible scenarios and should not be viewed as the most likely scenario. These cautionary statements qualify all forward looking statements attributable to us or persons acting on our behalf.

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Disclaimer

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Highlights

OPERATIONAL

  • Oil entitlement 15,800 bopd; gas deliveries 23 MMcfpd
  • Gas deliveries commenced to Ibom Power in January 2014; three new gas take-or-pay customers

signed

  • Ongoing gas infrastructure development – 37km Uquo to Oron gas pipeline completed; Train 2 of

Uquo gas processing facility commissioned

  • Acquisition and successful integration of East Horizon Gas Company
  • South east Niger Delta oil facilities completed and production commenced in Q1 2015
  • Exploration success at Uquo North East 1 prospect: gross 2C resources within licence 15 MMboe
  • Net 2P + 2C reserves plus resources up 17% to 414 MMboe (2013: 354 MMboe)

FINANCIAL

  • EBITDAX up 35% to $273 million (2013: $202 million)
  • Profit after tax up 41% to $55 million (2013: $39 million)
  • Balance sheet significantly strengthened with good progress on further optimising the capital

structure

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Operations overview

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Operational performance

Increased net reserves and resources

363 354 414

2012 2013 2014

(MMboe)

Increased oil entitlement

3,100 10,400 15,800

2012 2013 2014

(bopd)

First gas sales in south east

14 9 23

Ibom Power Unicem Total

Average daily deliveries (MMcfpd)

Increased oil liftings

3,600 9,000 10,000

2012 2013 2014

(bopd)

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South east overview

Customers and commercial progress

Customer Customer details Capacity Progress

Ibom Power Akwa Ibom State owned power station 190 MW power generation capacity First commercial delivery of gas in January 2014 Calabar NIPP Federal Government owned power station 560 MW power generation capacity Commenced delivery March 2015 UniCem Nigeria’s third largest cement factory 2.5 million tonnes annual production capacity Delivered NGC gas until Nov; Uquo gas thereafter Notore Leading fertiliser and agro-allied company 1,000 metric tonnes of daily ammonia production Commenced taking gas in Q1 2015 Alaoji NIPP Federal Government owned power station 1,074 MW power generation capacity Take-or-pay to commence in Q2 2015 Net reserves and resources split 91% 9% Gas Oil

Total: 130 (MMboe) 2P 2C Oil 8 5 Gas 65 52

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North west overview

2014 Highlights

Net reserves and resources split 47% 53% Gas Oil

Total: 222 (MMboe) 2P 2C Oil 68 50 Gas 80 24

  • Production – 52,500 bopd daily average gross production (2013: 51,600 bopd)
  • Entitlement – 15,800 bopd daily average net entitlement (2013: 10,400 bopd)
  • 24 wells drilled or worked over in 2014
  • 2014 capital investment - $408 million (Seven Energy 55% share)
  • 2015 capital budget, net to Seven Energy, approximately $165 million with agreement of budgetary controls with

NPDC and Seplat

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Strategic Alliance Agmt – Group accounting ($m)

Cost treatment on Balance Sheet and Income Statement

When the cost returns are received they are booked to fixed assets or operating costs and accounts payable or accruals depending on their nature and approval status. Operator submitted costs; approved

  • DR

Fixed assets (BS) 230

  • DR

Operating costs (IS) 129

  • CR

Accounts payable (BS) (359) Operator costs submitted; awaiting approval

  • DR

Fixed assets (BS) 178

  • DR

Operating costs (IS) 72

  • CR

Accruals (BS) (250)

Oil entitlement treatment

As the cost returns are received, Seven is entitled to recover “cost oil”: operating costs and intangible capex immediately and tangible capex over 5 years. Excess oil after cost recovery goes into the “profit oil” calculation (after taking into account Royalty and PPT); Seven Energy is entitled to a share of this. The entitlement, made up of current years cost recovery, plus prior years tangible capex amortisation and profit oil is recognised as a credit to cost of sales with the entitlement booked as inventory (underlift). Depletion is recorded on entitlement barrels at $15.7/bbl

  • DR

Inventory (BS) 536

  • CR

Cost of sales (IS) (536)

  • DR

Depletion (IS) 91

  • CR

Fixed Assets (BS) (91)

Revenue recognition

Under the accounting treatment, revenue is only recognised when the oil has been physically lifted from the terminal. At this point it is considered that the inventory (underlift) has been sold.

  • DR

Cost of sales (IS) 345

  • CR

Inventory (underlift) (BS) (345)

  • DR

Accounts receivable (BS) 345

  • CR

Revenue (IS) (345) 9

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Income statement

$m 2014 2013 Revenue 378 345 Cost of sales

  • Production expenses
  • Increase in underlift

Depletion (232) 191 (122) (171) 71 (68) Gross profit 215 177 Operating profit 148 126 Investment revenue

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Finance costs (76) (38) Foreign exchange gains/(losses) 8 (1) Profit before tax 80 88 Profit for the year 55 39

Profit for the year

  • Gas sales generated a $33m

increase to revenue with the first year of south east Niger Delta gas deliveries

  • Underlift increased by $191m due

to unlifted production entitlement

  • Production expenses up by $61m

due to increased SAA opex and full year of southeast operations

  • Increased depletion due to

increased SAA entitlement, gas production & infrastructure depletion

  • Increase in finance costs of $38m

due to higher net debt in 2014

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$55 $61 $21 $54 $29 $39 $33 $120 $5 $23

50 100 150 200 250

Profit 2013 Gas revenue Change in increase in underlift Production expenses Admin &

  • ther

expenses DD&A Depletion Net Finance & Forex costs Tax credit Profit 2014

$m

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Balance sheet

$m 2014 2013 Non-current assets 2,001 1,162 Current assets 376 214 Current liabilities (729) (675) Non-current liabilities (910) (305) Total Equity 737 396 Current borrowings 113 359 Non-current borrowings 654 171 Total net borrowings 767 530

2014 Capital Investment - $912m

Sm 2014 2013 OMLs 4, 38 & 41 408 338 Uquo field 160 157 Stubb Creek Field 6 11 Other 4 2 Total Additions 578 508 East Horizon Gas Company acquisition 270

  • Suntera (OML 905)

acquisition 64

  • Total capital investment

912 508 $767 $166 $200 $40 $7 $530 $165 $52 $33 $400 200 400 600 800 1000 1200 Opening net debt 2014 Accugas II & III raise RBL net drawdowns during the year Net rise from debt assumed during EHGC acquisition High yield bond placement Converitble Bonds repaid with HYB proceeds RBL repaid with HYB proceeds Working capital facility repaid with HYB proceeds Reduction from other movements Closing net debt 2014 $m

Net debt increase - $237m

  • Increase due to drawdown
  • f Accugas II & III for the

completion of the south east Niger Delta gas infrastructure and the acquisition of the East Horizon 128 km gas pipeline

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Cash flow

$m 2014 2013 Operating cash flows before movements in working capital 261 208 Working capital movements (120) (36) Net cash provided by operating activities 141 172 Net cash used in investing activities (479) (324) Net cash from financing activities 327 171 Net (decrease) / increase in cash and cash equivalents (11) 19 Cash and cash equivalents at beginning of year 50 32 Effect of foreign exchange rate changes (1) (1) Cash and cash equivalents at end of year 38 50

Movement in cash during the year Significant investment during 2014

  • Decrease in cash from operating

activities due to increased underlift, offset by increase in

  • pex payables
  • 48% increase in cash used in

investing activities due to acquisition activity in 2014

  • 91% increase in cash proceeds

from financing activity from significant debt and equity raises during the year

$50 $38 $335 $151 $106 $141 $174 $255

  • 400
  • 300
  • 200
  • 100

100 200 Opening cash 2014 Cash from

  • perations

Purchases of property, plant and equipment and intangible assets Acquisitions

  • f subsidiaries

(net of cash acquired) Interest and fees paid during the year Net cash proceeds from borrowings Proceeds from equity raise Other Closing cash 2014 $mn

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2015 funding plan

  • Accugas
  • New Accugas facility to refinance existing facilities into one well advanced
  • Credit approval in place for new Accugas facility from majority of lenders
  • Target financial close in mid May
  • Revolving Capital Facility
  • $50 million Revolving Capital Facility to be progressed after Accugas financial

close

  • Other sources of financing being pursued
  • Up to $75 million of equity or other funding sources
  • Total new sources of funds: $50 million up to $125 million

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Key 2015 initiatives

  • Progress construction of Oron to Creek Town gas pipeline, ensuring growth in gas

demand is met

  • Further develop strong gas delivery position in south east Niger Delta
  • Anticipate full utilisation of gas processing capacity in 2016
  • Develop south east Niger Delta oil production
  • Pre-FEED for Uquo NE-1 discovery
  • De-bottleneck Stubb Creek production facilities
  • Manage Strategic Alliance Agreement with Seplat
  • Ensure adherence to agreed 2015 budget
  • Reduce underlift position whilst meeting NPDC cash calls
  • Strict capital discipline

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