30 July 2013
DRAX GROUP PLC
(Symbol: DRX)
HALF YEAR RESULTS FOR THE SIX MONTHS ENDED 30 JUNE 2013
On track to become one of the world's largest renewable generators
Six months ended 30 June |
2013 |
2012 |
Key financial performance measures |
|
|
EBITDA (£ million) (1) |
120 |
154 |
Underlying earnings per share (pence) (2) |
17.3 |
28.9 |
Interim dividend (pence per share) (3) |
8.7 |
14.4 |
|
|
|
Statutory accounting measures |
|
|
Profit before tax (£ million) |
206 |
141 |
Reported basic earnings per share (pence) |
41 |
33 |
|
|
|
Financial and Operational Highlights
· H1 2013 underlying profits in line with expectations
· Year on year reduction reflects increasing carbon costs - including UK carbon tax from April
· Strong hedge - doubled 2014 forward sales in H1
· Strong balance sheet - £245 million net cash at 30 June 2013
Biomass Transformation Highlights
· First unit converted in April and performing to plan
· Capital investments on schedule and budget
· Construction of US-based pellet operations commenced
Dorothy Thompson, Chief Executive of Drax, said:
"In the first half of 2013 we have delivered good operating performance across the business during a period of extensive activity at the Drax site.
"The first converted unit was commissioned at the beginning of April, generating electricity from sustainable biomass in place of coal. The unit, which is the largest converted unit in the world, has been operating safely and delivered expected performance, using the interim storage and delivery systems in place. We will start commissioning the new bespoke systems later this year.
"We are investing significant capital this year and next to transform our business, with earnings during this period impacted by the increasing costs of carbon. However, as we move beyond this investment phase and replace substantial quantities of coal with sustainable biomass, we are confident that we will deliver attractive returns for our shareholders.
"We welcome the Government's recent announcements and consultation on the Feed-in Tariff with Contracts for Difference ("CFD") mechanism, which potentially provides additional options to support future unit conversions. We are participating in the consultation process and will assess whether these options are attractive to Drax."
H1 2013 Review
Financial
· EBITDA for H1 2013 down 22% at £120 million
- Year on year reduction reflects increasing carbon costs, with no free carbon allocation under EU ETS Phase III and initiation of the UK carbon tax from April
· Underlying earnings per share decreased 40% to 17 pence
- Includes impact of higher number of shares in issue following October 2012 placing
- Reported basic earnings per share of 41 pence include unrealised gains on derivative contracts of £122 million (and the associated tax), principally related to foreign currency hedging programme to support biomass procurement activities
· Now expect tax rate on underlying profits for full year 2013 to be in the mid-single digits range
- Impact of research and development tax relief and revaluation of deferred tax liability
- In future years expect our underlying tax rates to be more closely aligned with standard corporate tax rates
· Capital investment plans on track
- H1 2013 capital investment of £138 million, including £106 million for biomass transformation
- Full year 2013 capital investment guidance unchanged at c.£250 million to £300 million, including £50 million for plant efficiency and other projects (non-biomass transformation)
· Interim dividend of 8.7 pence per share, or £35 million (H1 2012: 14.4 pence per share,
or £53 million), in line with policy to distribute 50% of underlying earnings
· Strong balance sheet, with net cash of £245 million
- £75 million term loan agreed in April, underpinned by a guarantee from Infrastructure UK
- Replaces £50 million of the £100 million term loan facility agreed with the UK Green Investment Bank in December 2012
Operational
Six months ended 30 June |
2013 |
2012 |
Key operational performance measures |
Biomass |
Coal |
Group |
Forced outage rate (%) |
13.1 |
7.6 |
4.4 |
Planned outage rate (%) |
12.9 |
11.1 |
10.8 |
Availability (%) |
76 |
82 |
85 |
Electrical output (net sales) (TWh) |
0.7 |
11.9 |
13.6 |
· Maintaining world class standards of safety
- Total recordable injury rate(4) of 0.23 (H1 2012: 0.13), with an increase of more than 50% in man-hours worked at Drax Power Station
Coal
· Load factor 78% - continued high output due to good availability and plant despatch economics
· Forced outage rate - long-term target remains 5%
First Converted Unit
· Technical performance - outage rates and availability in line with plan
- Unit fuelled using existing co-firing systems
· Load factor 57% - temporary fuel delivery constraints
· Phased commissioning of new facilities beginning in Q4
- Remain confident that average availability for first converted unit will be 80% for 2013
· Expect to enter 2014 with:
- First unit fuelled by new on-site systems, with first 50 bespoke biomass rail wagons fully operational later in Q1
- First unit performance in line with operational guidance previously provided
Notes:
(1) EBITDA is profit before interest, tax, depreciation, amortisation and unrealised gains/losses on derivative contracts.
(2) H1 2013 underlying earnings per share exclude unrealised gains on derivative contracts of £122 million (H1 2012: £21 million) and the associated tax.
(3) Based on the number of shares in issue as at 30 June 2013 and 30 June 2012 respectively.
(4) Calculated as (lost time injuries + worse than first aid injuries) / hours worked x 100,000.
~~~~~~~~~~~~~~~~~~~~~~
Forward Looking Statements
This announcement may contain certain statements, statistics and projections that are or may be forward-looking. The accuracy and completeness of all such statements, including, without limitation, statements regarding the future financial position, strategy, projected costs, plans and objectives for the management of future operations of Drax Group plc ("Drax") and its subsidiaries (the "Group") are not warranted or guaranteed. By their nature, forward-looking statements involve risk and uncertainty because they relate to events and depend on circumstances that may occur in the future. Although Drax believes that the expectations reflected in such statements are reasonable, no assurance can be given that such expectations will prove to be correct. There are a number of factors, many of which are beyond the control of the Group, which could cause actual results and developments to differ materially from those expressed or implied by such forward-looking statements. These factors include, but are not limited to, factors such as: future revenues being lower than expected; increasing competitive pressures in the industry; and/or general economic conditions or conditions affecting the relevant industry, both domestically and internationally, being less favourable than expected. We do not intend to publicly update or revise these projections or other forward-looking statements to reflect events or circumstances after the date hereof, and we do not assume any responsibility for doing so.
~~~~~~~~~~~~~~~~~~~~~~~
Results presentation meeting and call-in arrangements
Management will host a presentation for analysts and investors at 9am (UK Time) today, Tuesday 30 July 2013, at Deutsche Bank, Winchester House, 1 Great Winchester Street, London, EC2N 2DB.
Would anyone wishing to attend please confirm by either e-mailing [email protected] or calling Jenny Scott at Brunswick Group on +44 (0) 20 7404 5959.
The meeting can also be accessed remotely via a conference call or alternatively via a live webcast, as detailed below. After the meeting, a video webcast and recordings of the call will be made available and access details for these recordings are also set out below.
A copy of the presentation will be made available from 7am (UK time) on Tuesday 30 July 2013 for download at: www.drax.com>>investors>>results_and_reports>>IR presentations>>2013 or use the link http://www.drax.com/investor/results_and_reports/presentations
For further information please contact Jenny Scott at Brunswick Group on +44 (0) 20 7404 5959.
Chairman's introduction
The Group performed well in the first half of the year. We have delivered profits in line with expectations, although lower than for the same period last year reflecting the increased cost of carbon. In accordance with our dividend policy, shareholders will receive an interim ordinary dividend of 8.7 pence per share in October, equivalent to approximately £35 million.
We started this year with our sights firmly set on converting our first generating unit to run on sustainable biomass in place of coal. The unit came on stream at the beginning of April and is performing to plan. We now have four months' valuable experience operating the largest converted unit in the world, which is a significant achievement.
We have set out plans to convert three of our six generating units and to become a predominantly biomass-fuelled generator. Much engineering and construction work is underway at the Drax Power Station site and we will start commissioning our new biomass receipt, storage and distribution systems later this year.
More than ever we are convinced of the important role that biomass has to play in the UK energy mix. However, biomass fuel must be underpinned by very robust sustainability standards. We demonstrate this in our own sourcing and supply chain, and continue to advocate and support the requirement for mandatory standards across our industry. This is simply doing the right thing and should underpin confidence in what is a cost effective, low carbon and reliable source of renewable power.
Downstream, our retail business continues to provide value to the Group as a direct, credit efficient route to market for our power, and increasingly our renewable power. Upstream, our developments in the US have started to take shape. Construction has started at our pellet plant site in Mississippi, whilst in Louisiana the second pellet plant site and the Baton Rouge port site are being mobilised for the start of construction.
As always I should like to thank all Group staff for their contribution to what has been a successful first half of the year.
Chief Executive's statement
Introduction
Profits for the first half of the year are lower than profits in the first half of 2012, but in line with expectations. At the beginning of this year, we entered into Phase III of the EU ETS and no longer receive a free carbon allocation. In addition, the UK carbon tax came into effect in April. As a result our carbon costs are higher, with a consequent impact on our profits. This is all well understood by shareholders and the stock market. Through these increased costs and Government's trajectory for increasing the UK carbon tax over time, there will be a growing downward pressure on the profitability of all coal-fired electricity generators. Expectations of our profit performance must be viewed in this context until biomass reaches an appropriate scale.
The highlight of the first six months of the year is undoubtedly the conversion of our first generating unit to burn sustainable biomass in place of coal. The unit was brought into service at the beginning of April and is performing in line with plan and safely.
Towards the end of April, we announced that we had agreed a £75 million amortising loan facility with Friends Life, underpinned by a guarantee from HM Treasury issued under the Infrastructure UK Guarantee Scheme, further enhancing our financing structure.
Our good operational performance during the first half of the year has supported both our contracted position and our ability to take advantage of market opportunities. Trading conditions in the markets in which we operate have been favourable and we have strengthened our contracted position, more than doubling our forward power sales for 2014 since the beginning of the year. We are now almost fully hedged for 2013 and well advanced for 2014.
Elsewhere in the business, we successfully concluded the contractual arrangements to commence construction of our two US-based pellet plants and of our US port facility. Finally, our retail business, Haven Power Limited ("Haven Power"), continues to provide a credit efficient route to market and has delivered significant growth in sales of almost 50% in the first half of the year.
Commodity markets
We have seen attractive dark green spreads, the difference between the price of power and the cost of coal and carbon, over the first six months of the year. The drivers for these attractive spreads are relatively stable gas and, therefore, power prices, very low coal prices and low carbon prices. However, as noted above, the introduction of both the full auctioning of EU emissions allowances from the start of the year and the UK carbon tax from April has increased costs for coal-fired generators.
Market bark spreads, the difference between power price plus renewable support and the cost of biomass, have fallen this year, principally as a result of currency effects, with a weaker British Pound Sterling and most biomass used for large scale power generation priced in US dollars or Euros. We have implemented an extensive foreign currency hedging programme to support our biomass procurement activities as detailed in the Operational and financial performance review.
Throughout the first half of the year, dark green spreads were higher than bark spreads. Looking forward, Government's announced annual increase in the UK carbon tax, whilst strengthening the case for biomass generation, is likely to erode the competitive position of coal-fired generation plant.
Generation performance
Our safety performance continues to be industry-leading at a time of considerable project activity and outage work. The engineering and construction work associated with our biomass conversion has continued apace in the first half of the year and we have completed the first of our two major planned outages. Compared to the same period last year we have seen an increase of more than 50% in the number of man-hours worked at the power station site.
We have enjoyed continued good operational performance from our coal units at Drax Power Station. Our load factor for the first half of the year has again been high compared to other coal and gas-fired plants, driven by our high efficiency, and the quality and competitiveness of the system support services we are able to offer the National Grid.
First unit conversion
After a one month outage to conduct the final stage of the necessary modifications to the boiler and through utilising, on a temporary basis, our existing biomass co-firing receipt, storage and handling systems, we started running our first converted biomass unit at the beginning of April.
We are very pleased with the technical performance to date, which has been in line with plan. The unit has achieved output levels of up to 585MW (c.10% lower than coal) with no loss of flexibility. To date, we have not encountered significant slagging, fouling or corrosion inside the boiler. Emissions of nitrogen oxides have been significantly lower than for the coal units. The efficiency modifications we have made so far have been effective and the overall combustion process is stable.
Technical availability of 76% and the outage rates set out in the Operational and financial performance review are largely as expected for this first newly converted unit.
The load factor of 57% was significantly lower than we expect to deliver in the future. Normally, biomass units would be expected to have very high load factors when available, reflecting the favourable economics of biomass generation. However, logistics have been challenging and as a result generation from this converted unit was materially constrained over the period by fuel availability. This was due to the temporarily limited biomass storage facilities on-site, as well as the use of some temporary supply chain facilities off-site pending delivery of the permanent facilities.
Later in the year we will begin a phased commissioning of the new on-site biomass receipt, storage and distribution systems, during which time we will gradually switch from the temporary arrangements to the purpose-built systems.
We remain confident that average availability for the first converted unit will be 80% for 2013 and that, thereafter, we will begin to deliver performance in line with operational guidance previously provided.
Next year will be characterised by continued transformation. We expect to enter 2014 with the first unit fuelled entirely by the new on-site systems and conversion work continuing on the second and third units. Our first 50 bespoke biomass rail wagons should be fully operational by the end of the first quarter and we are aiming to convert the second unit in the Summer.
Retail performance
Haven Power continues to provide us with a valuable, credit efficient alternative to trading through the wholesale market. Sales growth within the industrial and commercial, and small and medium enterprises markets remains the business priority. With significant growth achieved in the first half of the year we are confident in our ability to continue to grow our power sales to business customers.
Biomass supply chain
We continue to make good progress with our biomass sourcing. Further to securing the rights to sufficient fibre for the first unit conversion, we are well advanced with sourcing for the second unit and continue negotiations for the third.
The work we are doing on sustainability criteria for the biomass we procure continues to be industry-leading. All the biomass we source complies with our sustainability principles.
Other areas of the biomass fuel supply chain, namely port, shipping and rail arrangements, are progressing well. Agreements are in place for the expansion of import capacity through UK ports. In addition to the existing facilities at Port of Tyne, construction is now underway at Hull and Immingham, and we have further expansion at other UK ports under negotiation.
With the construction contracts concluded for our US pellet plants, one in each of the states of Louisiana (Morehouse) and Mississippi (Amite), we have now broken ground at Amite and expect to start construction at Morehouse in the Autumn. Construction of the port facility in Louisiana (Baton Rouge) is expected to begin shortly. We are targeting the first quarter of 2015 for the start of commercial operations at Amite and Baton Rouge and the second quarter for Morehouse, with full capacity reached six months later.
Legislative and regulatory framework
Sustainability criteria
The Government's response to its consultation on sustainability criteria for biomass is expected shortly. We continue to advocate the need for harmonised, mandatory sustainability criteria across the bioenergy sector. Through calculating the life cycle carbon footprint of all the biomass we buy, we are confident that we are delivering significant carbon savings compared to burning coal and further that our fibre sourcing strategy will meet the UK mandatory standard when it comes into effect.
Energy Bill
The Energy Bill, currently making its passage through Parliament, will enable the Government's Electricity Market Reform ("EMR") measures. In June 2013, the Government published some information on certain of the EMR measures, including further detail on the Feed-in Tariffs with Contracts for Difference ("CFD") for renewable technologies and the Capacity Market.
With respect to the CFD, draft strike prices and contract term principles were published. CFD are fixed price long-term contracts which, for new renewable investments, will replace the Renewables Obligation ("RO") from April 2017. Some details were also given in relation to the Final Investment Decision ("FID") Enabling CFD, which provides an alternative to the RO in advance of the CFD becoming available.
Detailed design proposals for a Capacity Market to ensure security of electricity supply were also published. Subject to legislation and state aid clearance, the Government will run the first Capacity Market auction in 2014 for delivery of capacity from the Winter of 2018/19. All existing and new forms of capacity will be eligible to participate in the Capacity Market, except for capacity supported by CFD, small scale Feed-in Tariffs or the RO, and interconnected capacity, although the latter may be eligible in future.
Earlier this month the draft EMR Delivery Plan was published for consultation. The document included information on the methodology and analysis behind the draft CFD strike prices, as well as the proposed draft reliability standard which will inform the level of capacity to be contracted through the Capacity Market.
We welcome the options which may now be available to us to secure support for future unit conversions and for our coal-fired units to participate in the Capacity Market. We have long believed that the introduction of a CFD mechanism would create a more level playing field for investment in renewables by new entrants and independent generators, and represent good value for consumers.
We will now engage fully in the consultation process and evaluate each of the options available.
Industrial Emissions Directive
Our work on the assessment of the options available to us for compliance with the more stringent emissions standards of the Industrial Emissions Directive from 2016 is well advanced. We remain on track to determine the optimal solution by the end of the year.
Creating low cost options for the future
We continue to pursue a number of low cost development options for the future. These include a fourth unit conversion at Drax, the White Rose Carbon Capture and Storage ("CCS") Project, securing new sites for further pellet plant and port facilities, and exploring options for alternative fuels and generation capacity.
Evaluation of a fourth unit conversion at Drax is underway, including assessment of whether this would be best delivered through modification of our existing co-firing systems, currently being utilised for our first unit, or investment in new bespoke facilities.
Together, Alstom UK Limited, Drax and BOC (a member of The Linde Group) have formed a consortium in support of the White Rose CCS Project, a proposed oxy-combustion CCS demonstration project of up to 450MW located at the Drax Power Station site. In March 2013, the Government announced that the project was one of two preferred bidders in the UK's CCS Commercialisation Programme Competition. We are now in discussion with Government to agree terms for a Front End Engineering and Design ("FEED") study. In addition, the Government submitted a funding application to the European Commission for the project under the second call of the European NER 300 programme.
A final investment decision is unlikely to be taken until 2015 and will be dependent on successful outcomes of the FEED study and the funding processes, as well as the proposed EMR mechanism to incentivise low carbon technologies. Whilst clearly an interesting and important project, we will only progress this investment if it delivers an appropriate return on capital, commensurate with any technical and commercial risks.
We continue to develop our options for further investments in biomass pellet plant facilities and port facilities in locations including the US and Latin America.
We believe that, as proposed, the UK Capacity Market has the potential to deliver attractive returns for investments. We will continue to assess these proposals and determine whether they give rise to any potentially valuable opportunities for the Group to benefit from our core competencies.
Delivering leading operating and cost performance will continue to be a key focus of our efforts as we implement our strategy to change from being a coal-fired generator burning some biomass to being a biomass-fired generator burning some coal. Transforming Drax into a predominantly biomass-fuelled generator will secure an attractive future for our business and our shareholders. It will also deliver cost effective, low carbon and reliable renewable power, which is good for the consumer, good for the environment and good for security of supply.
Operational and financial performance
Results of business
|
Six months ended 30 June 2013
£m |
Six months ended 30 June 2012
£m |
Total revenue |
918.5 |
867.9 |
|
|
|
Fuel costs in respect of generation(1) |
(409.0) |
(455.6) |
Cost of power purchases(2) |
(145.6) |
(57.8) |
Grid charges(3) |
(102.4) |
(81.1) |
Other retail costs(4) |
(45.5) |
(19.1) |
Total cost of sales |
(702.5) |
(613.6) |
Gross profit |
216.0 |
254.3 |
|
|
|
Other operating and administrative expenses excluding depreciation, amortisation and unrealised gains/(losses) on derivative contracts(5) |
(96.0) |
(100.5) |
EBITDA(6) |
120.0 |
153.8 |
|
|
|
Depreciation and amortisation |
(28.8) |
(28.2) |
Unrealised gains on derivative contracts |
122.4 |
21.0 |
Operating profit |
213.6 |
146.6 |
|
|
|
Net finance costs |
(8.0) |
(5.4) |
Profit before tax |
205.6 |
141.2 |
|
|
|
Tax: |
|
|
- Before impact of corporation tax rate change |
(41.7) |
(27.9) |
- Impact of corporation tax rate change |
- |
7.6 |
Tax charge |
(41.7) |
(20.3) |
|
|
|
Profit for the period attributable to equity shareholders |
163.9 |
120.9 |
|
|
|
Earnings per share |
pence |
pence |
- Statutory basic |
41 |
33 |
- Statutory diluted |
40 |
33 |
- Underlying basic and diluted(7) |
17 |
29 |
All results relate to continuing operations.
Notes:
(1) Fuel costs in respect of generation consist predominantly of coal, sustainable biomass and carbon dioxide ("CO2") emissions allowances, together with pond fines, petcoke and oil.
(2) Cost of power purchases represents power purchased in the market.
(3) Grid charges include transmission network use of system charges ("TNUoS"), balancing services use of system charges ("BSUoS") and distribution use of system charges ("DUoS").
(4) Other retail costs include broker fees, Renewables Obligation Certificates ("ROCs"), Levy Exemption Certificates ("LECs"), metering and Feed-in Tariff levelisation.
(5) Other operating and administrative expenses excluding depreciation, amortisation and unrealised gains and losses on derivative contracts include salaries, maintenance costs and other administrative expenses.
(6) EBITDA is defined as profit before interest, tax, depreciation, amortisation and unrealised gains and losses on derivative contracts.
(7) Calculated using underlying earnings, being profit attributable to equity shareholders adjusted to exclude the after tax impact of unrealised gains and losses on derivative contracts.
Introduction
EBITDA was £120 million for the six months ended 30 June 2013 compared to £154 million for the six months ended 30 June 2012.
Our results for the first half of 2013 were supported by good operational performance. The expected reduction in profitability compared to last year reflects increased carbon costs, with the removal of free carbon allowances in 2013 under Phase III of the EU ETS and implementation of the UK carbon tax from April, together adding £46 million to cost of sales in the first six months of 2013.
Looking forward, we have a strong near-term hedge in place through our contracted position, but earnings will be impacted by the increasing carbon costs until our biomass generation becomes more substantial.
As described in the Chief Executive's statement, our plans to become a predominantly biomass-fired power generator are well underway, with the successful conversion of our first unit in April. In support of these plans investment on-site at the Drax Power Station and through the biomass supply chain is continuing on schedule and is reflected in capital expenditure of £138 million in the first half of 2013 (2012: £90 million).
Our retail business, Haven Power, continues to deliver good volume growth with sales of 3.6TWh in the six months to 30 June 2013 compared to 2.5TWh during the same period in 2012.
Following much work last year and this, the balance sheet is strong. In April we agreed a £75 million amortising loan facility with Friends Life, underpinned by a guarantee from HM Treasury under the Infrastructure UK Guarantee Scheme. This replaces £50 million of the £100 million amortising loan facility agreed with the UK Green Investment Bank, which was signed in December 2012. With the full £225 million of term loans under our financing structure now drawn down, net cash at 30 June 2013 was £245 million.
The Board has resolved to pay an interim dividend for 2013 of 8.7 pence per share (£35 million) for the six months ended 30 June 2013, compared to 14.4 pence per share (£53 million) for the six months ended 30 June 2012.
This review provides further explanation and commentary in relation to our principal performance indicators and the results for the half year.
Segmental information
|
Six months ended 30 June 2013
£m |
Six months ended 30 June 2012
£m |
Revenue |
|
|
Power sales |
769.7 |
766.2 |
ROC and LEC sales |
1.6 |
17.2 |
Ancillary services income |
6.0 |
6.3 |
Other income |
7.6 |
4.7 |
Total generation revenue |
784.9 |
794.4 |
Retail revenue |
322.8 |
219.3 |
Intercompany sales |
(189.2) |
(145.8) |
Total Group revenue |
918.5 |
867.9 |
|
|
|
Cost of sales |
|
|
Fuel costs in respect of generation |
409.0 |
455.6 |
Generation cost of power purchases |
138.8 |
59.0 |
Generation grid charges |
30.6 |
32.4 |
Total generation cost of sales |
578.4 |
547.0 |
Retail cost of power purchases |
195.0 |
138.6 |
Retail grid charges |
71.8 |
48.7 |
Other retail costs |
46.5 |
25.1 |
Total retail cost of sales |
313.3 |
212.4 |
Intercompany purchases |
(189.2) |
(145.8) |
Total Group cost of sales |
702.5 |
613.6 |
|
|
|
Gross profit |
|
|
Generation gross profit |
206.5 |
247.4 |
Retail gross profit |
9.5 |
6.9 |
Group gross profit |
216.0 |
254.3 |
|
|
|
Operating and administrative expenses |
|
|
Generation operating and administrative expenses |
85.9 |
90.6 |
Retail operating and administrative expenses |
10.1 |
9.9 |
Group operating and administrative expenses |
96.0 |
100.5 |
|
|
|
EBITDA |
|
|
Generation EBITDA |
120.6 |
156.8 |
Retail EBITDA |
(0.6) |
(3.0) |
Group EBITDA |
120.0 |
153.8 |
Generation results
Revenue
Total generation revenue for the six months ended 30 June 2013 was £785 million compared to £794 million in 2012. Total generation revenue in 2013 includes power sales of £770 million (2012: £766 million), ROC and LEC sales of £2 million (2012: £17 million), ancillary services income of £6 million (2012: £6 million) and other income of £8 million (2012: £5 million).
Net power sold decreased to 12.6TWh in the six months ended 30 June 2013, compared to 13.6TWh in 2012, at a lower average achieved price of electricity of £50.1 per MWh this year, compared to £52.0 per MWh in 2012, resulting in an overall reduction in power sales from electricity generated. However, total power sales for 2013 also include £139 million of sales met through purchasing additional power in the market (see Cost of power purchases below) in comparison to £59 million in 2012.
Our average achieved price of electricity reflects our contracted position at the start of the year, as well as power prices during the first six months of the year. The decrease in achieved price is therefore a function of the timing of our sales and reflects the fall in gas and power prices towards the end of 2011.
ROC and LEC sales have decreased from £17 million in the six months to 30 June 2012 to £2 million in 2013.The timing of ROC sales is largely driven by a combination of Renewables Obligation deadlines and commercial considerations. Where ROCs and LECs have been generated but not sold they are held on the balance sheet. ROC and LEC assets at 30 June 2013 were £60 million compared to £41 million at 30 June 2012.
Generation revenue also includes income from the provision of ancillary services and the sale of by-products (ash and gypsum). In the six months ended 30 June 2013 these revenues were £14 million compared to £11 million in 2012.
Fuel costs (coal, biomass and other fuels)
Fuel costs in respect of generation were £409 million during the six months ended 30 June 2013 (2012: £456 million) with approximately 4.3 million tonnes of coal burnt in 2013 compared to 4.6 million tonnes for the same period in 2012. This coal was purchased from a variety of domestic and international sources under either fixed or variable priced contracts with different maturities.
In 2013, we burnt 0.4 million tonnes of biomass compared to 0.5 million tonnes during the same period in 2012. In 2013 most of the biomass relates to volumes burnt in our newly converted unit since April, whereas most of last year's burn (0.4 million tonnes) related to our biomass trials.
In addition, we burnt 0.3 million tonnes of pond fines during the first six months of 2013 (2012: 0.4 million tonnes). Pond fines are a coal mining residue, which trades at a significant discount to coal, requiring specific blending and handling techniques to burn in large volumes.
Coal comprised around 88% of total fuel burnt (by energy content) in the six months ended 30 June 2013 compared to 87% in 2012. Biomass comprised 7% of total fuel burnt in both years.
Our average cost of fuel per MWh (excluding CO2 emissions allowances) was £26.9 for the six months ended 30 June 2013, compared to £30.7 in 2012. The decrease in average fuel prices was largely driven by falling international coal prices, where continued over supply in the global traded market reflects high levels of US exports.
The impact of this price reduction was partially offset in the second quarter by the implementation of the UK carbon tax in April. The tax is charged as a levy on our coal deliveries and is recognised in the income statement as an additional fuel cost when we burn the related coal. The associated charge to the income statement was £14 million for the period to 30 June 2013.
The net cost of biomass represents an increasingly important element of our fuel costs. There are two parts to this cost; the gross cost of biomass delivered to the plant and the offsetting value of ROCs and LECs earned through burning biomass. The value of ROCs and LECs earned is recognised as a reduction in biomass costs in the period the related biomass is burnt. ROCs and LECs are held on the balance sheet within ROC and LEC assets until sold. Upon sale, income is recognised in revenue and a cost of sale recorded within fuel costs for the balance sheet value of the ROC or LEC.
Fuel costs (CO2 emissions allowances)
From 2013, we entered Phase III of the EU ETS, with no national CO2 emissions allowances allocation. We purchase CO2 emissions allowances under fixed price contracts with different maturity dates from a variety of domestic and international sources.
Our CO2 emissions allowances requirement for the six months ended 30 June 2013 was approximately 10.2 million tonnes, all of which were purchased. Our requirement for the first half of 2012 was 11.2 million tonnes, of which 6.5 million tonnes were purchased and 4.7 million tonnes allocated free under the UK NAP.
The average price expensed for purchased CO2 emissions allowances during the six months ended 30 June 2013 was £6.9 per tonne, compared to £5.9 per tonne in 2012, reflecting the timing of purchases under fixed price contracts in the forward and near-term markets. As a result, the cost of carbon allowances was £70 million in 2013 compared to only £38 million in 2012.
Cost of power purchases
We purchase power in the market when the cost of power in the market is below our marginal cost of production in respect of power previously contracted for generation and delivery by us, and to cover any shortfall in generation. For the six months ended 30 June 2013, the net cost of purchased power for the generation business was £139 million compared to £59 million incurred in 2012.
Grid charges
Generation grid charges for the six months ended 30 June 2013 were £31 million compared to £32 million in 2012.
As a result of these factors, generation gross profit for the six months ended 30 June 2013 was £207 million compared to £247 million in 2012.
Operating and administrative expenses
Generation other operating and administrative expenses before depreciation and amortisation were £86 million for the six months ended 30 June 2013 compared to £91 million in 2012.
The higher costs in the first half of 2012 included our obligations under the Community Energy Saving Programme, which ended in December 2012 (see note 12 to the condensed consolidated financial statements).
We continue to carefully control our cost base with our full year Group operating cost estimate (including retail operating costs) unchanged at £215 million.
Generation EBITDA for the six months ended 30 June 2013 was therefore £121 million compared to £157 million in 2012.
Retail results
Revenue
Haven Power have realised substantial growth so far this year, with sales volumes increasing from 2.5TWh in the six months ended 30 June 2012 to 3.6TWh in the six months ended 30 June 2013. This reflects planned growth in Haven Power's industrial and commercial customer base, along with growth in our sales to the small and medium enterprises market. As a result, retail sales revenue increased by almost 50% to £323 million for the six months to 30 June 2013 compared to £219 million in 2012.
Cost of power purchases
Retail cost of power purchases for the six months ended 30 June 2013 were £195 million compared to £139 million incurred in 2012, reflecting the rise in sales volumes.
Grid charges
Higher retail volumes, alongside increased charges, have also driven a rise in grid charges for the retail business to £72 million in the six months to 30 June 2013, from £49 million in 2012.
Other retail cost of sales
Other retail costs include broker fees, ROCs, LECs, metering and Feed-in Tariff ("FiT") costs and were £47 million in the six months ended 30 June 2013, compared to £25 million in 2012. In addition to higher volumes, expenditure continues to grow due to the increasing FiT levelisation costs being charged to suppliers.
As a result of these factors, retail gross profit for the six months ended 30 June 2013 was £9 million compared to £7 million in 2012.
Operating and administrative expenses
Retail other operating and administrative expenses before depreciation and amortisation were £10 million for both the six months ended 30 June 2013 and 2012.
Retail EBITDA for the six months ended 30 June 2013 was, therefore, a loss of £1 million compared to a loss of £3 million in 2012.
Central costs
Depreciation and amortisation
Depreciation and amortisation was £29 million for the six months ended 30 June 2013 and £28 million for the six months ended 30 June 2012.
Unrealised gains and losses on derivative contracts
The Group recognises unrealised gains and losses on forward contracts which meet the definition of derivatives under IFRSs. Where possible, we take the own use exemption for derivative contracts entered into and held for our own purchase, sale or usage requirements, including forward biomass and domestic coal contracts.
Mark-to-market movements on our derivative contracts that are considered to be effective hedges have been recognised through the hedge reserve, a component of shareholders' equity in the balance sheet. Movements in unrealised gains and losses recognised in the hedge reserve are mainly the result of unwinding mark-to-market positions relating to power and carbon delivered during the reporting period, and the recording of mark-to-market positions on power and carbon yet to be delivered at the end of the period.
The unrealised gains and losses recognised in the income statement arise from mark-to-market movements on our derivative contracts which do not qualify for hedge accounting; largely foreign exchange and financial coal.
The following table describes the movements in unrealised gains and losses and where they are recorded in our financial statements.
|
Six months ended
30 June 2013 £m |
Six months ended
30 June 2012 £m |
Year ended
31 December 2012
£m |
Net unrealised (losses)/gains in the balance sheet at beginning of the period |
(110.3) |
30.7 |
30.7 |
Unrealised gains/(losses) recognised in the income statement |
122.4 |
21.0 |
(36.1) |
Fair value losses recognised in the hedge reserve (a component of equity) |
(32.9) |
(0.6) |
(105.7) |
Premium on options |
0.1 |
0.5 |
0.8 |
Net unrealised (losses)/gains in the balance sheet at end of the period |
(20.7) |
51.6 |
(110.3) |
A weaker US dollar, relative to Sterling, at 31 December 2012 drove the net unrealised loss position recognised in the balance sheet at the start of 2013, which incorporated the mark-to-market position on a number of our foreign exchange contracts. These contracts reflect an extensive foreign currency hedging programme to support our biomass procurement activities. The programme covers all contracted and a substantial proportion of as yet uncontracted but forecast purchases and provides a significant degree of protection from adverse currency movements.
As the US dollar strengthened against Sterling during 2013, the unrealised loss position has reversed. With the majority of this movement relating to portions of the derivative contracts which do not qualify for hedge accounting, this gave rise to the £122 million unrealised gain recognised through the income statement during the first half of this year.
Power prices have remained relatively stable during the period, whereas carbon prices have fallen since the end of 2012. This resulted in an increase in the net unrealised loss position on our contracts which do qualify for hedge accounting, and is reflected in the £33 million loss recognised through the hedge reserve in the period.
In summary, after the changes in commodity prices and currency rates so far this year, the principal components of a net unrealised loss of £21 million recognised in the balance sheet at 30 June 2013 are unrealised losses on our carbon contracts and unrealised losses on financial coal contracts which have remained at a similar level to year end, largely offset by unrealised gains under our foreign exchange programme. Following a period of relatively stable power prices, the unrealised loss on our power book is not currently significant.
In considering mark-to-market movements, it is important to recognise that profitability is driven by our strategy to deliver market level dark green or bark spreads, not by the absolute price of electricity at any given date.
After allowing for depreciation, amortisation and unrealised gains and losses on derivative contracts, operating profit for the six months ended 30 June 2013 was £214 million compared to £147 million in 2012.
Interest
Net finance costs for the six months ended 30 June 2013 were £8 million compared to £5 million in 2012.
The higher costs in 2013 reflect interest incurred during the period on our new term loans, as described in Capital resources and refinancing.
Tax
The tax charge for the six months ended 30 June 2013 was £42 million (an effective rate of 20%). This includes previous years' research and development tax relief, now agreed with HMRC, resulting in a £6 million credit recognised in the period. The tax charge for the first six months of 2012 was £20 million (an effective rate of 14%). This included the impact of a reduction in the corporation tax rate to 24% from April 2012 on current and deferred tax liabilities and a revision to previous years' capital allowances claims, resulting in a further £8 million tax credit.
It is likely that our underlying effective tax rate for the full year will be relatively low as the Group will benefit from the research and development tax relief noted above, together with tax credits arising as we revalue our net deferred tax liability down to the 20% corporation tax rate which will be legislated in the second half of 2013. In future years we would expect our underlying tax rates to be more closely aligned with standard corporate tax rates.
Profit for the period and earnings per share
As a result of the above factors, profit attributable to equity shareholders for the six months ended 30 June 2013 was £164 million, compared to £121 million in 2012, and basic and diluted earnings per share were 41 pence and 40 pence, respectively, compared to 33 pence, basic and diluted, in 2012.
Underlying profit attributable to equity shareholders (that is profit excluding the after tax impact of unrealised gains and losses on derivative contracts) was £70 million for the six months ended 30 June 2013 compared to £106 million in 2012. Underlying basic and diluted earnings per share were 17 pence in 2013 compared to 29 pence in 2012.
Other key factors affecting the business
Outages and plant utilisation levels
|
Six months ended
30 June 2013 |
Six months
ended
30 June 2012 |
|
Biomass |
Coal |
|
Forced outage rate (%) |
13.1 |
7.6 |
4.4 |
Planned outage rate (%) |
12.9 |
11.1 |
10.8 |
Availability (%) |
76 |
82 |
85 |
Electrical output (net sales) (TWh) |
0.7 |
11.9 |
13.6 |
Notes:
The forced outage rate is expressed as a percentage of planned capacity available (that is, it includes a reduction for planned losses). The planned outage rate is expressed as a percentage of registered capacity.
Coal plant availability of 82% for the six months ended 30 June 2013 (2012: 85%) demonstrates our continuing leadership position in the coal-fired generation sector.
The forced outage rate of 7.6% for our coal plant for the six months ended 30 June 2013 is higher than our long-term target of 5%. We have continued to test a wide variety of advantaged fuels, for example coals with lower cost than the standard bituminous coal that we burn. Although some of these fuels have resulted in a higher number of plant integrity issues than we typically experience, the testing work is an important component of our drive to optimise value from our fuel mix, as well as the work to define our solution for compliance with the Industrial Emissions Directive (see Chief Executive's statement).
The planned outage rate for the coal plant for the six months ended 30 June 2013 was 11.1% compared to 10.8% in 2012. Our maintenance regime includes a major planned outage for each of our six units once every four years. Consequently, there is an irregular pattern to planned outages and associated expenditure, since in two of the four years two units will each undergo a major planned outage. We completed the first of two major planned outages for each year in the first six months of 2012 and 2013.
The resulting coal plant load factor was 78% for the period, which compares well with the average for other UK coal and gas plants and reflects our good availability and plant despatch economics.
At the beginning of April our first converted biomass unit was brought into service, utilising our existing biomass co-firing receipt, storage and handling systems. We have been pleased with the technical performance so far, which is in line with plan.
Availability for the period was 76%, with the issues driving the forced outage rate of 13.1% largely as expected for a newly converted unit. The planned outage rate of 12.9% reflects scheduled inspection work as well as the impact of a suspension of fuel deliveries to allow for work to be completed on our rail loop upgrade.
As described in the Chief Executive's statement, the load factor for the period of 57% was significantly lower than we expect to achieve in the future. Logistics have been challenging for our temporary systems, with only limited on-site storage available until the new systems are operational. In addition, reliability issues with coal wagons converted to transport biomass have further restricted fuel deliveries, with only limited capacity in place to receive biomass by road. As a result, operation from this first converted unit was materially constrained over the period by fuel availability.
Later in the year we will be commencing a phased commissioning of the new biomass receipt, storage and distribution systems and we expect the first unit to operate entirely on the new on-site systems by the end of the year. The first two sets of our new rail wagons will also be fully operational by the end of the first quarter in 2014. We remain confident that average availability for the first converted unit will improve to around 80% for 2013 and that thereafter we will begin to deliver performance in line with the operational guidance previously provided.
The load factor for the plant as a whole for the six months ended 30 June 2013 was 77% compared to 82% in 2012, reflecting a decrease in electrical output (net sales) to 12.6TWh in 2013, compared with the record output of 13.6TWh in 2012.
Health and safety
Our lost time injury rate and total recordable injury rate were 0.09 and 0.23, respectively, for the six months ended 30 June 2013 compared to 0.04 and 0.13 in 2012. These industry-leading safety statistics have been delivered against a backdrop of an increase of more than 50% in man-hours worked in the first half of 2013, compared to the same period in 2012.
Liquidity and capital resources
Net cash including short-term investments was £245 million at 30 June 2013 compared to £311 million at 31 December 2012 and £233 million at 30 June 2012. Cash and short-term investments were £460 million as at 30 June 2013, compared to £402 million at 31 December 2012 and £241 million at 30 June 2012. An analysis of cash flows is set out in the table below.
Analysis of cash flows
|
Six months ended
30 June 2013 £m |
Six months
ended
30 June 2012
£m |
Cash generated from operations |
129.3 |
162.9 |
Income taxes paid |
(13.2) |
(30.2) |
Other losses |
(0.2) |
(0.5) |
Net interest paid |
(5.0) |
(3.6) |
Net cash from operating activities |
110.9 |
128.6 |
Cash flows from investing activities |
|
|
Purchases of property, plant and equipment |
(133.2) |
(76.8) |
Short-term investments |
10.0 |
20.0 |
Net cash used in investing activities |
(123.2) |
(56.8) |
Cash flows from financing activities |
|
|
Equity dividends paid |
(43.8) |
(43.1) |
New borrowings |
125.0 |
- |
Issue of shares under employee share schemes |
1.7 |
- |
Repayment of borrowings |
(0.1) |
(0.1) |
Other financing costs |
(2.3) |
- |
Net cash from/(used in) financing activities |
80.5 |
(43.2) |
Net increase in cash and cash equivalents |
68.2 |
28.6 |
Cash and cash equivalents at 1 January |
371.7 |
202.8 |
Cash and cash equivalents at 30 June |
439.9 |
231.4 |
Short-term investments at 30 June |
20.0 |
10.0 |
Borrowings at 30 June |
(214.8) |
(8.2) |
Net cash at 30 June |
245.1 |
233.2 |
Cash generated from operations was £129 million in the six months ended 30 June 2013 compared to £163 million in 2012, driven by a decrease of £34 million in EBITDA, as described above.
Net income taxes paid were £13 million in the six months ended 30 June 2013 compared to £30 million in 2012. 2012 and 2013 payments included settlement of the 2011 and 2012 liability, respectively.
Net cash used in investing activities includes payments in respect of capital expenditure of £133 million in the six months ended 30 June 2013 and £77 million in 2012 (see Capital expenditure). 2013 includes a decrease of £10 million in short-term investments compared to a £20 million decrease in 2012, comprising cash deposits with a maturity of more than three months at inception.
Net cash flows from financing activities of £81 million in the six months ended 30 June 2013, consisted of £125 million of new borrowings (see Capital resources and refinancing) and equity dividends paid of £44 million. Net cash used in financing activities in the six months ended 30 June 2012 was £43 million, being equity dividends paid.
The increase in cash and cash equivalents was, therefore, £68 million in the six months ended 30 June 2013, compared to an increase of £29 million in 2012. Drax's policy is to invest available cash in short-term bank, building society or other low risk deposits.
Capital resources and refinancing
In April 2013 we agreed a new £75 million amortising term loan facility, maturing in June 2018, with Friends Life, underpinned by a guarantee from HM Treasury under the Infrastructure UK Guarantee Scheme. This replaces £50 million of the £100 million amortising term loan facility agreed with the Green Investment Bank, signed in December 2012.
The new loan facility enhances the existing financing structure executed last year by providing additional liquidity to the Group and ensuring a smoother profile of debt maturities. Furthermore, the all-in cost of the new facility is very competitive.
The financing structure also incorporates the remaining £50 million amortising term loan from the Green Investment Bank, a £100 million amortising term loan facility with the M&G UK Companies Financing Fund and a £400 million working capital and letter of credit facility. The term loans have varying maturity profiles ranging from four to eight years, whilst the working capital and letter of credit facility is due to mature in April 2016.
In addition, a commodity trading facility also executed in December 2012, allows us to transact prescribed volumes of commodity trades at attractive prices without the requirement to post collateral. This facility has been operating well during the first half of the year, offering trading counterparties uncapped access to the security package available to our senior lenders. Combined with other steps taken over the past three years to limit our requirements to post collateral, this is allowing the Group to operate comfortably at sub-investment grade level.
Going concern
We acknowledge guidance on going concern for companies preparing financial statements. We have significant headroom in our new banking facilities, a recent history of cash generation, strong covenant compliance and good visibility in near-term forecasts due to our progressive hedging strategy. Our Business Plan, taking account of our capital investment plans and reasonably possible changes in trading performance, shows that we should be able to operate within the level of our current banking facilities.
After considering the principal risks and uncertainties set out below, the directors are satisfied that the Group has adequate resources to continue in operational existence for the foreseeable future, a period of not less than 12 months from the date of this report. Accordingly, they continue to adopt the going concern basis in preparing the Half year report.
Seasonality of borrowing
Our business is seasonal with higher electricity prices and despatch in the Winter period and lower despatch in the Summer months, when prices are lower and plant availability is affected by planned outages.
Accordingly, cash flow during the Summer months is materially reduced due to the combined effect of lower prices and output, while maintenance expenditures are increased during this period due to major planned outages. As noted above (Capital resources and refinancing), we have a £400 million working capital and letter of credit facility, and it is envisaged that this facility will assist in managing the cash low points in the cycle if required.
Capital expenditure
Fixed asset additions were £138 million in the six months ended 30 June 2013 compared to £90 million in 2012.
Our biomass transformation investments remain on schedule and comprise the following expenditure to date.
|
Cumulative to 31 December 2012 £m |
6 months to 30 June 2013 £m |
Cumulative to 30 June 2013 £m |
Drax site |
177.9 |
67.0 |
244.9 |
US pellet operations |
0.8 |
31.4 |
32.2 |
Other supply chain |
4.8 |
7.8 |
12.6 |
Total biomass capital expenditure |
183.5 |
106.2 |
289.7 |
Additions in 2013 include £67 million for on-site biomass infrastructure at the Drax Power Station site. This work includes construction of new biomass fuel receipt, storage and distribution systems, sufficient to handle the 7 to 8 million tonnes of fuel per annum required for three converted units. We expect construction work on the remaining on-site infrastructure to be largely complete by the end of 2014.
A further £31 million of capital expenditure in the period relates to investment in our US Gulf based pellet operations. We are developing two pellet plants, with a combined capacity of 900,000 tonnes of pellet production per annum, and a port facility with export capacity of up to 3 million tonnes per annum. We are targeting the first half of 2015 for commercial operations to begin at these facilities.
Expected full year capital expenditure for 2013 continues to be in the region of £250 million to £300 million, including £50 million for plant efficiency and other projects unrelated to our biomass plans.
Principal risks and uncertainties
We manage the commercial and operational risks faced by the Group in accordance with policies approved by the Board. We set out in our 2012 Annual report and accounts (pages 32-35) the principal risks and uncertainties that could impact performance. These remain unchanged, and are as follows:
· Commodity market price risk
· Counterparty risk
· Power and renewables market liquidity risk
· Biomass market risk
· Plant operating risk
· Regulatory and political risk
Related parties
The Group set out in its 2012 Annual report and accounts (page 122) the related party transactions arising. There have been no material changes since the Annual report and accounts were published.
Positions under contract for 2013, 2014 and 2015
We continue to follow our stated trading strategy of making steady forward power sales with corresponding purchases of CO2 emissions allowances and fuel purchases. Our aim is to deliver market level dark green or bark spreads across all traded market periods and, as part of this strategy, we retain power to be sold into the prompt (within season) power markets. As at 22 July 2013, the commodity positions under contract for 2013, 2014 and 2015 were as set out below.
|
2013 |
2014 |
2015 |
Power sales (TWh) comprising: |
24.4 |
17.1 |
5.1 |
· Fixed price power sales (TWh) at an average achieved price (per MWh) |
23.1
@ £51.4 |
14.5
@ £53.5 |
3.2
@ £56.1 |
· Fixed margin and structured power sales (TWh) |
1.3 |
2.6 |
1.9 |
CO2 emissions allowances hedged, including market purchases and structured contracts (TWh equivalent) |
23.2 |
14.5 |
4.5 |
Solid fuel at fixed price/hedged, including structured contracts (TWh equivalent) |
25.6 |
22.6 |
13.1 |
Fixed price power sales include approximately 1.3TWh supplied to Centrica in the period 1 January 2013 to 22 July 2013 under the five year 300MW baseload contract which commenced on 1 October 2010.
Fixed margin power sales include approximately 1.3TWh in 2013, 2.6TWh in 2014 and 1.9TWh in 2015, in connection with the above contracts.
Under these contracts the Group will supply power on terms which include Centrica paying for coal, based on international coal prices, and delivering matching CO2 emissions allowances amounting in aggregate to approximately 2.4 million tonnes in 2013 and 2014 and approximately 1.8 million tonnes in 2015.
The contracts provide the Group with a series of fixed dark green spreads, with the spreads having been agreed in October 2009.
Distributions
Distribution policy
The Board has previously committed to target a pay-out ratio of 50% of underlying earnings (being profit attributable to equity shareholders adjusted to exclude the after tax impact of unrealised gains and losses on derivative contracts) in each year. Underlying earnings for the period ending 30 June 2013 were £70 million.
Dividends paid
On 18 February 2013, the Board resolved, subject to approval by shareholders at the Annual General Meeting on 24 April 2013, to pay a final dividend for the year ended 31 December 2012 of 10.9 pence per share (£44 million). The final dividend was subsequently paid on 17 May 2013.
Dividends proposed
On 29 July 2013, the Board resolved to pay an interim dividend for the six months ended 30 June 2013 of 8.7 pence per share (£35 million), representing 50% of underlying earnings for the period. The interim dividend will be paid on or before 11 October 2013 and shares will be marked ex-interim dividend on 25 September 2013.
Directors' responsibility statement
We confirm that to the best of our knowledge:
(a) the condensed set of financial statements has been prepared in accordance with IAS 34 "Interim Financial Reporting";
(b) the interim management report includes a fair review of the information required by DTR 4.2.7R (indication of important events during the first six months and description of principal risks and uncertainties for the remaining six months of the year); and
(c) the interim management report includes a fair review of the information required by DTR 4.2.8R (disclosure of related party transactions and changes therein).
Condensed consolidated income statement
|
|
Six months ended 30 June |
Year ended 31 December |
|
Notes |
2013
(Unaudited)
£m |
2012
(Unaudited)
£m |
2012
(Audited)
£m |
Revenue |
|
918.5 |
867.9 |
1,779.8 |
|
|
|
|
|
Fuel costs in respect of generation |
|
(409.0) |
(455.6) |
(929.2) |
Cost of power purchases |
|
(145.6) |
(57.8) |
(141.7) |
Grid charges |
|
(102.4) |
(81.1) |
(167.8) |
Other retail costs |
|
(45.5) |
(19.1) |
(30.2) |
Total cost of sales |
|
(702.5) |
(613.6) |
(1,268.9) |
Gross profit |
|
216.0 |
254.3 |
510.9 |
|
|
|
|
|
Other operating and administrative expenses |
|
(124.8) |
(128.7) |
(271.0) |
Unrealised gains/(losses) on derivative contracts |
|
122.4 |
21.0 |
(36.1) |
Operating profit |
|
213.6 |
146.6 |
203.8 |
|
|
|
|
|
Interest payable and similar charges |
|
(9.0) |
(6.4) |
(15.3) |
Interest receivable |
|
1.0 |
1.0 |
1.7 |
Profit before tax |
|
205.6 |
141.2 |
190.2 |
|
|
|
|
|
Tax |
5 |
(41.7) |
(20.3) |
(26.4) |
Profit for the period attributable to equity holders |
|
163.9 |
120.9 |
163.8 |
|
|
|
|
|
|
|
|
|
|
Earnings per share |
|
pence |
pence |
pence |
- Basic |
6 |
41 |
33 |
44 |
- Diluted |
6 |
40 |
33 |
44 |
All results relate to continuing operations.
Underlying earnings and underlying earnings per share are set out in note 6.
Condensed consolidated statement of comprehensive income
|
Six months ended 30 June |
Year ended
31 December |
|
2013 (Unaudited) £m |
2012 (Unaudited) £m |
2012
(Audited)
£m |
Profit for the period |
163.9 |
120.9 |
163.8 |
Actuarial losses on defined benefit pension scheme |
(2.9) |
(13.7) |
(9.0) |
Deferred tax on actuarial losses on defined benefit pension scheme |
0.7 |
3.3 |
2.1 |
Fair value losses on cash flow hedges |
(32.9) |
(0.6) |
(105.7) |
Deferred tax on cash flow hedges |
7.6 |
0.9 |
26.0 |
Other comprehensive expense for the period |
(27.5) |
(10.1) |
(86.6) |
Total comprehensive income for the period attributable to equity holders |
136.4 |
110.8 |
77.2 |
Condensed consolidated balance sheet
|
|
As at 30 June |
As at 31 December |
|
Notes |
2013 (Unaudited) £m |
2012 (Unaudited) £m |
2012
(Audited)
£m |
Assets |
|
|
|
|
Non-current assets |
|
|
|
|
Intangible assets |
|
11.7 |
10.7 |
49.7 |
Property, plant and equipment |
|
1,464.8 |
1,257.3 |
1,360.6 |
Derivative financial instruments |
|
71.8 |
35.3 |
7.7 |
|
|
1,548.3 |
1,303.3 |
1,418.0 |
Current assets |
|
|
|
|
Inventories |
|
207.5 |
162.3 |
157.6 |
ROC and LEC assets |
|
60.0 |
41.2 |
18.7 |
Trade and other receivables |
|
169.7 |
179.2 |
224.8 |
Derivative financial instruments |
|
77.2 |
108.8 |
37.6 |
Short-term investments |
|
20.0 |
10.0 |
30.0 |
Cash and cash equivalents |
|
439.9 |
231.4 |
371.7 |
|
|
974.3 |
732.9 |
840.4 |
Liabilities |
|
|
|
|
Current liabilities |
|
|
|
|
Trade and other payables |
|
282.4 |
258.6 |
275.9 |
Current tax liabilities |
|
3.1 |
22.3 |
14.6 |
Borrowings |
|
0.3 |
7.9 |
0.3 |
Derivative financial instruments |
|
133.4 |
65.3 |
100.4 |
|
|
419.2 |
354.1 |
391.2 |
Net current assets |
|
555.1 |
378.8 |
449.2 |
Non-current liabilities |
|
|
|
|
Borrowings |
|
214.5 |
0.3 |
90.4 |
Derivative financial instruments |
|
36.3 |
27.2 |
55.2 |
Provisions |
|
31.9 |
30.9 |
31.5 |
Deferred tax liabilities |
|
202.4 |
201.3 |
170.7 |
Retirement benefit obligations |
|
43.5 |
48.8 |
42.1 |
|
|
528.6 |
308.5 |
389.9 |
Net assets |
|
1,574.8 |
1,373.6 |
1,477.3 |
Shareholders' equity |
|
|
|
|
Issued equity |
|
46.4 |
42.2 |
46.4 |
Capital redemption reserve |
|
1.5 |
1.5 |
1.5 |
Share premium |
|
422.3 |
420.7 |
420.7 |
Merger reserve |
|
710.8 |
710.8 |
710.8 |
Hedge reserve |
10 |
(41.7) |
63.6 |
(16.4) |
Retained profits |
|
435.5 |
134.8 |
314.3 |
Total shareholders' equity |
|
1,574.8 |
1,373.6 |
1,477.3 |
Condensed consolidated statement of changes in equity
|
Issued equity £m |
Capital redemption reserve
£m |
Share premium
£m |
Merger reserve £m |
Hedge reserve £m |
Retained profits
£m |
Total
£m |
At 1 January 2012 |
42.1 |
1.5 |
420.7 |
710.8 |
63.3 |
65.0 |
1303.4 |
Profit for the year |
- |
- |
- |
- |
- |
163.8 |
163.8 |
Other comprehensive expense |
- |
- |
- |
- |
(79.7) |
(6.9) |
(86.6) |
Total comprehensive (expense)/income for the year |
- |
- |
- |
- |
(79.7) |
156.9 |
77.2 |
Equity dividends paid |
- |
- |
- |
- |
- |
(95.7) |
(95.7) |
Issue of share capital |
4.3 |
- |
- |
- |
- |
183.4 |
187.7 |
Movement in equity associated with share-based payments |
- |
- |
- |
- |
- |
4.7 |
4.7 |
At 31 December 2012 |
46.4 |
1.5 |
420.7 |
710.8 |
(16.4) |
314.3 |
1,477.3 |
At 1 January 2012 |
42.1 |
1.5 |
420.7 |
710.8 |
63.3 |
65.0 |
1,303.4 |
Profit for the period |
- |
- |
- |
- |
- |
120.9 |
120.9 |
Other comprehensive income/(expense) |
- |
- |
- |
- |
0.3 |
(10.4) |
(10.1) |
Total comprehensive
income for the period |
- |
- |
- |
- |
0.3 |
110.5 |
110.8 |
Equity dividends paid |
- |
- |
- |
- |
- |
(43.1) |
(43.1) |
Movement in equity associated with share-based payments |
- |
- |
- |
- |
- |
2.4 |
2.4 |
Issue of share capital |
0.1 |
- |
- |
- |
- |
- |
0.1 |
At 30 June 2012 |
42.2 |
1.5 |
420.7 |
710.8 |
63.6 |
134.8 |
1,373.6 |
At 1 January 2013 |
46.4 |
1.5 |
420.7 |
710.8 |
(16.4) |
314.3 |
1,477.3 |
Profit for the period |
- |
- |
- |
- |
- |
163.9 |
163.9 |
Other comprehensive expense |
- |
- |
- |
- |
(25.3) |
(2.2) |
(27.5) |
Total comprehensive (expense)/income for the period |
- |
- |
- |
- |
(25.3) |
161.7 |
136.4 |
Equity dividends paid |
- |
- |
- |
- |
- |
(43.8) |
(43.8) |
Movement in equity associated with share-based payments |
- |
- |
- |
- |
- |
3.3 |
3.3 |
Issue of share capital |
- |
- |
1.6 |
- |
- |
- |
1.6 |
At 30 June 2013 |
46.4 |
1.5 |
422.3 |
710.8 |
(41.7) |
435.5 |
1,574.8 |
Condensed consolidated cash flow statement
|
|
Six months ended 30 June |
Year ended
31 December |
|
Notes |
2013 (Unaudited) £m |
2012 (Unaudited) £m |
2012
(Audited)
£m |
Cash generated from operations |
11 |
129.3 |
162.9 |
263.2 |
Income taxes paid |
|
(13.2) |
(30.2) |
(50.6) |
Other losses |
|
(0.2) |
(0.5) |
(0.8) |
Interest paid |
|
(5.8) |
(4.6) |
(10.6) |
Interest received |
|
0.8 |
1.0 |
1.9 |
Net cash from operating activities |
|
110.9 |
128.6 |
203.1 |
Cash flows from investing activities |
|
|
|
|
Purchases of property, plant and equipment |
|
(133.2) |
(76.8) |
(206.0) |
Short-term investments |
8 |
10.0 |
20.0 |
- |
Net cash used in investing activities |
|
(123.2) |
(56.8) |
(206.0) |
Cash flows from financing activities |
|
|
|
|
Equity dividends paid |
7 |
(43.8) |
(43.1) |
(95.7) |
Proceeds from issue of share capital |
|
1.7 |
- |
187.7 |
Repayment of borrowings |
|
(0.1) |
(0.1) |
(10.5) |
New borrowings |
|
125.0 |
- |
100.0 |
Other financing costs paid |
|
(2.3) |
- |
(9.7) |
Net cash from/(used in) financing activities |
|
80.5 |
(43.2) |
171.8 |
Net increase in cash and cash equivalents |
8 |
68.2 |
28.6 |
168.9 |
Cash and cash equivalents at beginning of the period |
|
371.7 |
202.8 |
202.8 |
Cash and cash equivalents at end of the period |
|
439.9 |
231.4 |
371.7 |
Notes to the condensed consolidated financial statements
1. General information
Drax Group plc (the "Company") is incorporated in England and Wales under the Companies Act. The Company and its subsidiaries (together the "Group") operate in the electricity generation and supply industry within the UK. The address of the Company's registered office and principal establishment is Drax Power Station, Selby, North Yorkshire YO8 8PH, United Kingdom.
2. Basis of preparation
The condensed consolidated financial statements have been prepared using accounting policies consistent with International Financial Reporting Standards ("IFRSs") and in accordance with IAS 34 "Interim Financial Reporting".
The information for the year ended 31 December 2012 does not constitute statutory accounts as defined in Section 434 of the Companies Act 2006. A copy of the statutory accounts for that year has been delivered to the Registrar of Companies. The auditor's report on those accounts was not qualified, did not draw attention to any matters by way of emphasis and did not contain statements under Section 498(2) or (3) of the Companies Act 2006.
The condensed consolidated financial statements were approved by the Board on 29 July 2013.
Adoption of new and revised accounting standards
In 2012, a number of new standards and interpretations became effective as noted in the 2012 Annual report and accounts (page 89). The adoption of these standards and interpretations has not had a material impact on the financial statements of the Group.
Since the 2012 Annual report and accounts was published no significant new standards and interpretations have been issued. The following new and revised standards became effective during 2013:
- IFRS 10 "Consolidated financial statements" - effective for accounting periods beginning on or after 1 January 2013.
- IFRS 11 "Joint arrangements" - effective for accounting periods beginning on or after 1 January 2013.
- IFRS 12 "Disclosure of interests in other entities" - effective for accounting periods beginning on or after 1 January 2013.
- IFRS 13 "Fair value measurement" - effective for accounting periods beginning on or after 1 January 2013.
- IAS 19 (revised) "Employee benefits" - effective for accounting periods beginning on or after 1 January 2013.
The adoption of these standards has not had a material impact on the financial statements of the Group.
3. Significant accounting policies
The accounting policies adopted are consistent with those followed in the preparation of the Group's Annual report and accounts for the year ended 31 December 2012.
4. Segmental reporting
Information reported to the Board for the purposes of assessing performance and making investment decisions is organised into two operating segments. The Group's operating segments under IFRS 8 are as follows:
· Generation - the generation of electricity at the Drax Power Station.
· Retail - the supply of electricity to retail customers in the small and medium enterprise and industrial and commercial markets.
The measure of profit or loss for each reportable segment, presented to the Board on a regular basis is EBITDA, with sales between segments being carried out at arm's length. Assets and working capital are monitored on a Group basis with no separate disclosure of asset by segment made in the management accounts, and hence no separate asset disclosure is provided in this Half year report.
Segment revenues and results
The following is an analysis of the Group's results by reporting segment in the six months ended 30 June 2013:
|
Six months ended 30 June 2013 (Unaudited) |
|
Generation
£m |
Retail
£m |
Eliminations
£m |
Consolidated
£m |
Revenue |
|
|
|
|
External sales |
595.7 |
322.8 |
- |
918.5 |
Inter‑segment sales |
189.2 |
- |
(189.2) |
- |
Total revenue |
784.9 |
322.8 |
(189.2) |
918.5 |
|
|
|
|
|
Result |
|
|
|
|
Segment EBITDA |
120.6 |
(0.6) |
- |
120.0 |
|
|
|
|
|
Central costs |
|
|
|
|
Depreciation and amortisation |
|
|
|
(28.8) |
Unrealised gains on derivative contracts |
|
|
|
122.4 |
Operating profit |
|
|
|
213.6 |
Net finance costs |
|
|
|
(8.0) |
Profit before tax |
|
|
|
205.6 |
The following is an analysis of the Group's results by reporting segment in the six months ended 30 June 2012:
|
Six months ended 30 June 2012 (Unaudited) |
|
Generation
£m |
Retail
£m |
Eliminations £m |
Consolidated £m |
Revenue |
|
|
|
|
External sales |
648.6 |
219.3 |
- |
867.9 |
Inter‑segment sales |
145.8 |
- |
(145.8) |
- |
Total revenue |
794.4 |
219.3 |
(145.8) |
867.9 |
|
|
|
|
|
Result |
|
|
|
|
Segment EBITDA |
156.8 |
(3.0) |
- |
153.8 |
|
|
|
|
|
Central costs |
|
|
|
|
Depreciation and amortisation |
|
|
|
(28.2) |
Unrealised gains on derivative contracts |
|
|
|
21.0 |
Operating profit |
|
|
|
146.6 |
Net finance costs |
|
|
|
(5.4) |
Profit before tax |
|
|
|
141.2 |
The following is an analysis of the Group's results by reporting segment in the year ended 31 December 2012:
|
Year ended 31 December 2012 (Audited) |
|
Generation
£m |
Retail
£m |
Eliminations
£m |
Consolidated
£m |
Revenue |
|
|
|
|
External sales |
1,328.4 |
451.4 |
- |
1,779.8 |
Inter‑segment sales |
301.6 |
- |
(301.6) |
- |
Total revenue |
1,630.0 |
451.4 |
(301.6) |
1,779.8 |
|
|
|
|
|
Result |
|
|
|
|
Segment EBITDA |
303.0 |
(4.6) |
- |
298.4 |
|
|
|
|
|
Central costs |
|
|
|
|
Depreciation and amortisation |
|
|
|
(58.5) |
Unrealised losses on derivative contracts |
|
|
|
(36.1) |
Operating profit |
|
|
|
203.8 |
Net finance costs |
|
|
|
(13.6) |
Profit before tax |
|
|
|
190.2 |
The accounting policies of the reportable segments are the same as the Group's accounting policies which are described in the Group's latest Annual report and accounts. The revenue and results of both segments are subject to seasonality as detailed in the Operational and financial performance review.
Major customers
Total revenue for the six months ended 30 June 2013 includes £106.3 million derived from one customer (2012: £217.5 million derived from one customer), representing 10% or more of the Group's revenue for the period.
5. Taxation
The income tax expense reflects the estimated effective tax rate on profit before taxation for the Group and the movement in the deferred tax balance in the period, so far as it relates to items recognised in the income statement.
Changes in the rate of corporation tax
Following the announcement of the 2012 Budget, the Finance Act 2012 (the "Act") was enacted by Parliament in July 2012. The Act confirmed reductions in the rate of corporation tax from 26% to 24% from April 2012, and from 24% to 23% from April 2013.
In the 2013 Budget, the Government proposed reductions in the rate of corporation tax from 23% to 21% from 1 April 2014, and a further reduction in corporation tax to 20% from 1 April 2015. These reductions have not been recognised in the condensed consolidated financial statements as they had not been substantively enacted at the balance sheet date.
|
Six months ended 30 June |
Year ended 31 December |
|
2013 (Unaudited)
£m |
2012 (Unaudited)
£m |
2012
(Audited)
£m |
Tax charge comprises: |
|
|
|
Current tax |
1.7 |
18.4 |
31.4 |
Deferred tax: |
|
|
|
- Before impact of corporation tax rate change |
40.0 |
9.5 |
10.1 |
- Impact of corporation tax rate change |
- |
(7.6) |
(15.1) |
Tax charge |
41.7 |
20.3 |
26.4 |
6. Earnings per share
Basic earnings per share is calculated by dividing the earnings attributable to ordinary shareholders by the weighted average number of ordinary shares outstanding during the period. In calculating diluted earnings per share the weighted average number of ordinary shares outstanding during the period is adjusted, when relevant, to take account of share options and contingently issuable shares in relation to the Group's share-based incentive plans. The underlying earnings per share has been calculated after excluding the after tax impact of marking-to-market derivative contracts which are not hedged.
Reconciliations of the earnings and weighted average number of shares used in the calculation are set out below.
|
Six months ended 30 June |
Year ended 31 December |
|
2013 (Unaudited) £m |
2012 (Unaudited) £m |
2012 (Audited)
£m |
Earnings: |
|
|
|
Earnings attributable to equity holders of the Company for the purposes of basic and diluted earnings |
163.9 |
120.9 |
163.8 |
After tax impact of unrealised gains and losses on derivative contracts |
(94.2) |
(15.3) |
29.0 |
Underlying earnings attributable to equity holders of the Company |
69.7 |
105.6 |
192.8 |
|
Six months ended 30 June |
Year ended 31 December |
|
2013 (Unaudited) |
2012 (Unaudited) |
2012 (Audited) |
Number of shares: |
|
|
|
Weighted average number of ordinary shares for the purposes of basic earnings per share (millions) |
402.0 |
364.9 |
371.7 |
Effect of dilutive potential ordinary shares under share plans |
3.4 |
3.6 |
3.5 |
Weighted average number of ordinary shares for the purposes of diluted earnings per share (millions) |
405.4 |
368.5 |
375.2 |
Earnings per share - basic (pence) |
41 |
33 |
44 |
Earnings per share - diluted (pence) |
40 |
33 |
44 |
Underlying earnings per share - basic (pence) |
17 |
29 |
52 |
Underlying earnings per share - diluted (pence) |
17 |
29 |
51 |
7. Dividends
|
Six months ended 30 June |
Year ended 31 December |
|
2013
(Unaudited)
£m |
2012 (Unaudited)
£m |
2012
(Audited)
£m |
Amounts recognised as distributions to equity holders in the period (based on the number of shares in issue at the record date): |
|
|
|
Final dividend for the year ended 31 December 2012 of 10.9 pence per share paid 17 May 2013 |
43.8 |
- |
- |
Interim dividend for the year ended 31 December 2012 of 14.4 pence per share paid 12 October 2012 |
- |
- |
52.6 |
Final dividend for the year ended 31 December 2011 of 11.8 pence per share paid 11 May 2012 |
- |
43.1 |
43.1 |
|
43.8 |
43.1 |
95.7 |
On 29 July 2013, the Board resolved to pay an interim dividend for the six months ended 30 June 2013 of 8.7 pence per share (equivalent to approximately £35 million) on or before 11 October 2013. The interim dividend of 8.7 pence per share has not been included as a liability as at 30 June 2013.
8. Net cash
|
As at 30 June |
As at 31 December |
|
2013 (Unaudited)
£m |
2012 (Unaudited)
£m |
2012
(Audited)
£m |
Net cash at 1 January |
311.0 |
225.2 |
225.2 |
Increase in cash and cash equivalents |
68.2 |
28.6 |
168.9 |
Decrease in short-term investments |
(10.0) |
(20.0) |
- |
Increase in net borrowings |
(124.1) |
(0.6) |
(83.1) |
Net cash at period end |
245.1 |
233.2 |
311.0 |
Refinancing
As set out in our latest Annual report and accounts, in December 2012 we completed the refinancing of our revolving credit facilities which were due to mature in April 2014. This facility was replaced with a larger £400m revolving credit facility which matures in April 2016 and can be used for both letters of credit and working capital purposes. In addition to this facility we executed two new committed term loans of £100 million each with the Prudential M&G UK Companies Financing Fund and the UK Green Investment Bank. The loans have six to eight year maturities. At the same time as concluding the financing arrangements above, we also executed a commodities trading line, which allows trading counterparties to benefit from the security package offered to senior lenders rather than Drax posting collateral for certain volumes of trades. The Prudential M&G UK Companies Financing Fund loan was fully drawn down at the year end.
On 24 April 2013 we announced that we had agreed a £75 million amortising loan facility maturing in June 2018 with Friends Life, underpinned by a guarantee from HM Treasury issued under the Infrastructure UK Guarantee Scheme. This replaces £50 million of the £100 million amortising loan facility agreed with the UK Green Investment Bank, signed in December 2012.
The remaining £50 million UK Green Investment Bank loan and the £75 million Friends Life loan were fully drawn down on 29 and 30 April 2013, respectively.
9. Financial instruments
The Group's financial instruments consist of borrowings, cash and liquid resources, items that arise directly from its operations and derivative contracts. Cash and cash equivalents, short-term investments, trade and other receivables and trade and other payables generally have short times to maturity. For this reason, their carrying values approximate fair value. The Group's borrowings relate principally to amounts drawn down against term loans, the carrying amounts of which approximate their fair values by virtue of being floating rate instruments.
The fair values of the Group's derivative financial instruments which are marked-to-market and recorded in the balance sheet were as follows:
|
As at 30 June |
As at 31 December |
|
2013 (Unaudited) £m |
2012 (Unaudited) £m |
2012 (Audited) £m |
Assets |
|
|
|
Commodity contracts |
46.7 |
125.2 |
35.4 |
Forward foreign currency exchange contracts |
102.3 |
18.9 |
9.9 |
|
149.0 |
144.1 |
45.3 |
|
|
|
|
Liabilities |
|
|
|
Commodity contracts |
(150.5) |
(71.9) |
(84.8) |
Forward foreign currency exchange contracts |
(19.2) |
(20.6) |
(70.8) |
|
(169.7) |
(92.5) |
(155.6) |
As described in full in our latest Annual report and accounts, the fair value of commodity contracts and forward foreign currency exchange contracts is largely determined by comparison between forward market prices and the contract price, therefore these contracts have been grouped into Level 2 within the fair value hierarchy in their entirety.
The Group has no financial instruments with fair values derived solely from unadjusted quoted prices (Level 1) or unobservable inputs (Level 3). There have been no transfers of any assets or liabilities between levels of the fair value hierarchy during the current or preceding period.
10. Hedge reserve
The Group's cash flow hedges relate to commodity contracts (principally commitments to sell power), forward foreign exchange contracts and interest rate swaps. Amounts are recognised in the hedge reserve as the designated contracts are marked-to-market at each period end for the effective portion of the hedge, which is generally 100% of the relevant contract. Amounts held within the hedge reserve are then released as the related contract matures and the hedged transaction impacts profit or loss. For power sales contracts, this is when the underlying power is delivered.
The expected release from equity of post‑tax hedging gains and losses is as follows:
|
As at 30 June 2013 (Unaudited) |
|
Within
1 year
£m |
1-2 years £m |
>2 years £m |
Total
£m |
Commodity contracts |
(40.9) |
(5.3) |
0.2 |
(46.0) |
Forward foreign currency exchange contracts |
3.5 |
(0.1) |
0.9 |
4.3 |
|
(37.4) |
(5.4) |
1.1 |
(41.7) |
|
As at 30 June 2012 (Unaudited) |
|
Within
1 year
£m |
1-2 years £m |
>2 years
£m |
Total £m |
Commodity contracts |
47.7 |
11.4 |
0.2 |
59.3 |
Forward foreign currency exchange contracts |
5.0 |
(0.7) |
- |
4.3 |
|
52.7 |
10.7 |
0.2 |
63.6 |
|
As at 30 December 2012 (Audited) |
|
Within
1 year
£m |
1-2 years
£m |
>2 years £m |
Total
£m |
Commodity contracts |
(11.6) |
(3.7) |
- |
(15.3) |
Forward foreign currency exchange contracts |
(0.9) |
(0.2) |
- |
(1.1) |
|
(12.5) |
(3.9) |
- |
(16.4) |
11. Cash generated from operations
|
Six months ended 30 June |
Year ended 31 December |
|
2013 (Unaudited) £m |
2012 (Unaudited) £m |
2012
(Audited)
£m |
Profit for the period |
163.9 |
120.9 |
163.8 |
Adjustments for: |
|
|
|
Interest payable and similar charges |
9.0 |
6.4 |
15.3 |
Interest receivable |
(1.0) |
(1.0) |
(1.7) |
Tax charge (note 5) |
41.7 |
20.3 |
26.4 |
Depreciation and amortisation |
28.8 |
28.2 |
58.5 |
Unrealised (gains)/losses on derivative contracts |
(122.4) |
(21.0) |
36.1 |
Defined benefit pension scheme charge |
2.9 |
2.9 |
5.7 |
Non-cash charge for share-based payments |
3.3 |
2.4 |
4.7 |
Operating cash flows before movement in working capital |
126.2 |
159.1 |
308.8 |
Changes in working capital: |
|
|
|
Increase in inventories |
(49.9) |
(24.6) |
(19.9) |
Decrease in receivables |
55.2 |
90.1 |
44.5 |
Increase/(decrease) in payables |
6.4 |
(47.3) |
(33.9) |
Total decrease/(increase) in working capital |
11.7 |
18.2 |
(9.3) |
Decrease/(increase) in carbon assets |
38.0 |
- |
(39.0) |
(Increase)/decrease in ROC and LEC assets |
(41.3) |
(9.1) |
13.4 |
Defined benefit pension scheme contributions |
(5.3) |
(5.3) |
(10.7) |
Cash generated from operations |
129.3 |
162.9 |
263.2 |
12. Contingent liabilities
Community Energy Saving Programme
Drax Power Limited ("Drax Power") was obliged under the Electricity and Gas (Community Energy Saving Programme) Order 2009 ("CESP") to deliver energy saving measures to domestic consumers in specific low income areas of Great Britain during the period 1 October 2009 to 31 December 2012 (the "Obligation period"). Drax Power's obligation was to deliver 895,138 lifetime tonnes of CO2 savings. It entered into an agreement with a third party, pursuant to which the third party was obliged to deliver its CESP obligation, for a total cost of £17 million. The third party has failed to comply fully with its obligation under the agreement, leaving a significant shortfall against the CESP obligation. Drax Power intends to commence legal proceedings for breach of contract against the third party.
Drax Power entered into further agreements with additional third parties in order to rectify this shortfall so far as practicable. Having taken account of the additional measures under those arrangements, the Office of Gas and Electricity Markets ("Ofgem") announced in May 2013 that Drax Power had achieved 37.1% of its CESP target at the end of the Obligation period. At the same time Ofgem also announced that it was launching an investigation into those companies that had failed to achieve their energy efficiency targets, including Drax Power.
The Gas and Electricity Markets Authority ("the Authority") is the enforcement authority in relation to CESP. Subject to the findings of Ofgem's investigation, it will produce a statement of case or decide that there is no case to answer. In the case of the former, a recommendation to an enforcement committee of the Authority will be made on enforcement action. The Authority has wide powers of enforcement, including issuing a penalty or other means of enforcement. Ofgem has also indicated that a settlement committee of the Authority will be established to consider proposals made by obligated parties to settle investigations.
Representatives of Drax Power had an initial meeting with the Ofgem enforcement team in June 2013, following which it has received a formal information request. Drax Power will co-operate fully with the investigation. At this stage, it is not possible to predict accurately what, if any, enforcement action may be taken.
In the absence of any communication on enforcement subject to the findings of the investigation, it is not practicable to measure reliably the financial impact, if any. Accordingly, no provision has been recognised within these condensed consolidated financial statements in relation to this matter.
Glossary
Ancillary services
Services provided to National Grid Company used for balancing supply and demand or maintaining secure electricity supplies within acceptable limits. They are described in Connection Condition 8 of the Grid Code.
Availability
Average percentage of time the units were available for generation.
Average achieved price
Power revenues divided by volume of net sales (includes imbalance charges).
Average capture price
Revenue derived from bilateral contracts divided by volume of net merchant sales.
Balancing Mechanism
The sub-set of the market through which the System Operator can call upon additional generation/consumption or reduce generation/consumption, through market participants' bids and offers, in order to balance the system minute-by-minute.
Baseload
Running 24 hours per day, seven days per week remaining permanently synchronised to the system.
Bilateral contracts
Contracts with counterparties and power exchange trades.
Company
Drax Group plc.
Dark green spread
The difference between the price available in the market for sales of electricity and the marginal cost of production (being the cost of coal and other fuels including CO2 emissions allowances).
Direct injection co‑firing
The process whereby biomass is fed directly (that is, avoiding the pulverising mills) to the burners situated in the boiler walls.
EBITDA
Profit before interest, tax, depreciation and amortisation and unrealised gains/(losses) on derivative contracts.
EU ETS
The EU Emissions Trading System is a mechanism introduced across the EU to reduce emissions of CO2; the scheme is capable of being extended to cover all greenhouse gas emissions.
Forced outage
Any reduction in plant availability, excluding planned outages and restrictions arising from fuel and logistics constraints.
Forced outage rate
The capacity which is not available due to Forced outages expressed as a percentage of the maximum theoretical capacity, less planned outage capacity.
Frequency response service
Services purchased by National Grid Company to maintain system frequency.
Grid charges
Includes transmission network use of system charges ("TNUoS"), balancing services use of system charges ("BSUoS") and distribution use of system charges ("DUoS").
Group
Drax Group plc and its subsidiaries.
IFRSs
International Financial Reporting Standards.
LECs
Levy Exemption Certificates. Evidence of Climate Change Levy exempt electricity supplies generated from qualifying renewable sources.
Load factor
Net sent out generation as a percentage of maximum sales.
Lost time injury rate (LTIR)
The frequency rate is calculated on the following basis: lost time injuries/hours worked x 100,000. Lost time injuries are defined as occurrences where the injured party is absent from work for more than 24 hours.
Net Balancing Mechanism
Net volumes attributable to accepted bids and offers in the Balancing Mechanism.
Net cash/(debt)
Comprises cash and cash equivalents, short-term investments less borrowings net of deferred finance costs.
Net merchant sales
Net volumes attributable to bilateral contracts and power exchange trades.
Net sales
The aggregate of net merchant sales and net Balancing Mechanism.
Occupational health and safety assessment series (OHSAS)
The OHSAS specification gives requirements for an occupational health and safety management system to enable an organisation to control occupational health and safety risks and improve its performance.
Planned outage
A period during which scheduled maintenance is executed according to the plan set at the outset of the year, excluding the periods during which units are undergoing conversion to become biomass-fuelled.
Planned outage rate
The capacity not available due to planned outages expressed as a percentage of the maximum theoretical capacity.
Pond fines
Coal dust and waste coal from the cleaning and screening process which can be used as an alternative fuel for power generation.
Power exchange trades
Power sales or purchases transacted on the APX UK power trading platform.
Power revenues
The aggregate of bilateral contracts and Balancing Mechanism income/expense.
ROCs
Renewables Obligation Certificates.
Summer
The calendar months April to September.
Technical availability
Total availability after planned and forced outages.
Through-the-mill co-firing
The process whereby biomass passes first through the pulverising mills before going to the burners situated in the boiler walls.
Total recordable injury rate (TRIR)
The frequency rate is calculated on the following basis: (lost time injuries + worse than first aid injuries)/hours worked x 100,000.
UK NAP
UK National Allocation Plan.
Underlying earnings per share
Calculated as profit attributable to equity holders, adjusted to exclude the after tax impact of unrealised gains and losses on derivative contracts, divided by the weighted average number of ordinary shares outstanding during the period.
Winter
The calendar months October to March.
