(SSE.L) Scottish & Southern Energy PLC Buy/Sell

FINANCIAL RESULTS FOR CONTINUING OPERATIONS

Six months ended 30 September
(£m, at actual exchange rate) 2009 2008 % change

Business performance
Operating profit 1,149 1,079 6
Pre-tax profit 649 558 16
Earnings 554 431 29
Earnings per share 22.5p 17.2p3 31

Statutory results
Operating profit 1,404 943 49
Pre-tax profit 944 564 67
Earnings 696 406 71
Earnings per share 28.3p 16.2p3 75
Dividend per share 13.65p 12.64p 8

Steve Holliday, Chief Executive, said:

"We have made good operational and financial progress against our priorities for this year and have delivered a very strong financial performance in the first half. Our pre-tax profits were up 16%, supported by lower financing costs, delivering higher operating cash flows. We have now filed or implemented new rate plans for over 60% of our US rate base and are on track to deliver this year's investment programme of £3.4bn, financed through internal cash flows and borrowings.

As we look to the future our focused strategy is being confirmed by the changing energy landscape, which creates a number of organic growth opportunities for National Grid. With the right regulatory frameworks this will create significant value for our shareholders."
CHIEF EXECUTIVE'S REVIEW

National Grid has made a very good start to what is expected to be a strong financial year. This is despite the prevailing economic conditions, which have marginally affected our distribution businesses particularly in the US. We have made good progress on our stated priorities for 2009/10:- delivering our disciplined investment programme, progressing with our US regulatory filings and driving efficiency through the phased introduction of our operating model. Looking forward, the energy landscape is changing, creating a number of organic growth opportunities for National Grid.

Priorities for 2009/10

Our investment pipeline remains strong. In the UK electricity and gas markets, investment is being driven by changes in sources of gas supply and electricity generation (c.40%), and the need for asset replacement (c.60%). In the US electricity and gas markets, investment is being driven by customer additions (c.20%), the need for asset replacement (c.50%), system reinforcement (c.20%) and the emerging need for renewable generation (c.10%).

To date this year we have invested £1.5bn and are on target to invest around £3.4bn for the full year, growing our asset base. This is supported by current rate plans and long term contracts and is being financed from internal cash flow and borrowings.

Our financial position remains robust. Net operating cash flows are £747m higher than the previous period reflecting a favourable working capital movement. We have completed our funding requirement of £2.5bn for 2009/10 and have already pre-funded £1.3bn of our funding requirement for 2010/11. This year National Grid has issued long term bonds totalling over $2bn, from its Upstate New York regulated entity, Niagara Mohawk, and Massachusetts Electric at competitive rates. This is part of our programme to reallocate debt to our US operating companies.

Our net finance costs for this period have decreased by £20m to £504m. This reflects our variable rate debt benefiting from lower interest rates, along with UK deflation positively affecting our index linked debt. We have taken full advantage of these lower rates, fixing the majority of our variable rate debt portfolio for both the current year and 2010/11.

We are committed to financing our business in a manner consistent with maintaining an efficient balance sheet and optimising our cost of capital. We expect all credit metrics to improve this year, primarily due to the reduction in our interest charge. Moody's Investor Services, Fitch Ratings and Standard & Poor's have all reaffirmed our credit ratings with stable outlook.

We continue to make progress on our rate case filings in the US. This financial year we have made filings in Massachusetts Electric Company and Narragansett Electric. In addition we plan to file the Niagara Mohawk electric rate case in early 2010 and intend to file a rate case for our Colonial Gas business in the first quarter of 2010/11. At the same time we plan to make a consolidated filing, combining our Boston and Essex gas businesses into a single rate plan, greatly simplifying and improving the transparency of our Massachusetts gas regulatory arrangements.

We continue to drive efficiency through the phased introduction of our operating model. We expect that our 2009/10 regulated controllable costs (excluding bad debts) as a proportion of our asset base will reduce significantly from the 8.1% reported for 2008/09. We continue to drive procurement costs down through a combination of leveraging National Grid's scale, unit price reductions and a decrease in the number of suppliers. We remain on track with delivery of our KeySpan synergy savings, at 30 September 2009 we had achieved a run rate of $140m.

Potential growth opportunities

When we set out our strategy in November 2006, we noted the significant requirement for investment in our chosen markets, the UK and US, driven largely by the need for asset replacement, renewable energy policy and customer connections. Since that time, there have been clear developments in both UK and US energy policy and the regulatory and commercial regimes are now beginning to take shape. In the main they are being driven by specific national and state targets for renewable energy supply and reductions in carbon emissions.

This changing energy landscape will create a number of opportunities for National Grid and other energy companies. These will include the need for investment in renewable generation, new transmission systems to connect new nuclear stations and onshore and offshore wind generation, smart grids, carbon capture and storage projects, interconnectors and strategic gas storage. Whilst it is unclear today which of these projects will be appropriate for National Grid or their precise timing, we expect that greater clarity will emerge as UK and US energy policies continue to crystallise and appropriate regulatory frameworks are put in place. We are clear that we will adopt a rigorous approach to the assessment of these opportunities as they emerge and will be selective about which we pursue. We will only undertake investments that produce an attractive and predictable return for shareholders.

DIVIDEND

Reflecting the positive outlook for the year, the Board has approved an 8% increase in the interim dividend to 13.65p per ordinary share ($1.1480 per American Depositary Share) in line with its long term policy. The interim dividend is to be paid on 20 January 2010 to shareholders on the register as at 4 December 2009. A scrip dividend alternative will be offered.

OUTLOOK

Current performance remains in line with our expectations.

We continue to expect a strong performance from our Transmission and Electricity Distribution and Generation businesses. Our Gas Distribution business will benefit from increases in net revenues under our UK and US rate plans, but will be impacted by negative timing differences, resulting in lower operating profit in this business.

Net interest charges will benefit from low inflation and the majority of our variable rate debt having been fixed at low interest rates. Our full year effective tax rate is expected to be in line with last year.

Overall we are well positioned to deliver another year of strong performance.

Unless otherwise stated, all financial commentaries are given on a business performance basis at actual exchange rates. Business performance represents the results for continuing operations before exceptional items, mark-to-market remeasurements of commodity contracts and financial instruments that are held for economic hedging purposes but did not achieve hedge accounting, and US stranded cost recoveries. Commentary provided in respect of results after exceptional items, mark-to-market remeasurements and US stranded cost recoveries is described as 'statutory'.

REVIEW OF RESULTS AND FINANCIAL POSITION

Operating profit was £1,149m, up 6% on the prior period (up 2% on a constant currency basis4). This was primarily driven by good results in our Transmission and Electricity Distribution and Generation businesses partially offset by timing related items in our US Gas Distribution business. Operating profit performance in the first half of the year reflected the expected seasonality in our US businesses.

Net finance costs were £504m, 4% lower than the prior period, reflecting lower interest rates and RPI deflation benefiting the accretion on index linked bonds. We expect this trend to continue through to the full year but lessen as RPI inflation returns. Profit before tax was up 16% to £649m. The tax charge on profit was £93m, £32m lower than the prior period, with the first half tax charge under IAS34 reflecting discrete items of £67m and the geographical and seasonal split of our earnings. For the full year we expect our effective tax rate to be in line with last year. Earnings were up £123m on the prior period at £554m. Earnings per share increased 31% from 17.2p in the first half last year to 22.5p.

Exceptional items and remeasurements for continuing operations increased statutory earnings by £142m after tax. After these items and minority interests, statutory earnings for continuing operations attributable to shareholders were £696m - statutory basic earnings per share from continuing operations were 28.3p compared with 16.2p for the prior period.

Operating cash flows from continuing operations, before exceptional items, remeasurements, stranded cost recoveries and taxation, were £1,607m, £747m higher than the prior period.

Organic investment in our continuing businesses was £1.5bn, in line with our plans for the year.

Our net debt fell to £21.98bn at 30 September 2009 compared with £22.67bn at 31 March 2009, reflecting the impact of the weakening of the US dollar - pound exchange rate on our dollar denominated debt.

Further information about our principal risks and uncertainties for the next six months of the financial year is provided in Note 13 on page 25.

Summary results Six months ended 30 September
(£m) 2009 2008 % change
Revenue and other operating income 1,826 1,975 (8)
Operating costs (978) (1,188) (18)
Depreciation and amortisation (211) (196) 8
Operating profit - actual exchange rate 637 591 8
Operating profit - constant currency 637 611 4

Operating profit by geographical segment Six months ended 30 September
(£m, at constant currency) 2009 2008 % change

Operating profit 637 611 4
Capital investment Six months ended 30 September
(£m, at actual exchange rate) 2009 2008 % change

Capital investment 660 756 (13)

Transmission operating profit was up 8% at £637m. Our allowed UK transmission regulated revenue increased by 6.7% for electricity and 3.8% for gas at 1 April 2009 in line with our RPI + X price control allowances. This resulted in operating profit from our UK regulated revenue being £60m higher than the prior period. This was partially offset by operating profit lower in the US by £15m largely due to timing differences. Operating profit from our French Interconnector, which had a particularly strong performance last year, was lower by £22m. Other items increased operating profit by £3m. The period on period movement in exchange rates had a £20m positive benefit on Transmission operating profit.

Capital investment in Transmission was £660m. Large schemes in the UK include load related investment in the Thames estuary and transmission investment in renewable generation (which earns an enhanced return). Investment in our US transmission networks includes reliability spend in New York and investment on the New England East-West Solution (NEEWS) project, where we earn an enhanced Federal Energy Regulatory Commission (FERC) return on equity of 12.89%.

Summary results Six months ended 30 September
(£m) 2009 2008 % change
Revenue and other operating income 1,767 1,863 (5)
Operating costs (1,331) (1,432) (7)
Depreciation and amortisation (183) (157) 17
Operating profit - actual exchange rate 253 274 (8)
Operating profit - constant currency 253 276 (8)

Operating profit by geographical segment Six months ended 30 September
(£m, at constant currency) 2009 2008 % change

Operating profit 253 276 (8)
Capital investment Six months ended 30 September
(£m, at actual exchange rate) 2009 2008 % change
UK capex 104 72 44
UK repex 233 207 13

Capital investment 541 449 20

Gas Distribution operating profit decreased by £21m during the period to £253m. In the UK, net regulated revenues were up £23m, reflecting increases under the price control allowance. In addition the re-phasing of UK billing between the first and second half of the year increased operating profit by £104m. In the US, where the vast majority of annual revenue is collected in the second half of the year, net revenues were up £16m on the prior period. This good performance comes on the back of last year's significant over recovery, which together with negative timing impacts in this half year, has led to a £142m period on period decrease in operating profit. Most of this year's under recovery is expected to reverse in the second half. In addition, as anticipated, the US recession is reducing our customers' ability to pay their bills with operating profit down by £16m as a result of an increase in bad debts. Other items reduced UK and US net operating profit by £8m. The period on period movement in exchange rates had a £2m positive benefit on operating profit.

During the period, together with our Gas Distribution alliance partnerships in the UK, we have replaced around 1,026km of gas mains, resulting in total replacement expenditure (repex) of £233m. In our US operations customer connections have slowed as a result of the US recession. This period we have added around 19,000 new customers. Overall, our investment in network infrastructure projects in the UK and US resulted in total capital expenditure (including repex) of £541m this period, 20% up on the prior period.

We continue to make good regulatory progress in the US. On 14 May 2009 our Niagara Mohawk gas rate case, recommended by the New York Public Service Commission (NYPSC) staff, was approved in full with a base allowed return of 10.2% and provided for a $39m increase in revenues. The revenue increase came into effect on 20 May. On 29 May 2009 the New Hampshire gas rate case (covering around 1% of our US rate base) was approved. We were disappointed with the allowed return on equity of 9.54%, which is out of line with other regulatory decisions and we subsequently asked the New Hampshire Public Utilities Commission to reconsider the decision. Last week, the Commission denied our motion for reconsideration and we are now considering our next steps.

Next year we plan to make a rate case filing for Colonial Gas and a consolidated filing, combining our Boston and Essex businesses into a single rate plan. Our continued programme of refiling rate cases will benefit both customers and shareholders by supporting much needed investment and recovery of costs.

REVIEW OF ELECTRICITY DISTRIBUTION AND GENERATION OPERATIONS

Summary results Six months ended 30 September
(£m) 2009 2008 % change
Revenue and other operating income* 1,947 1,854 5
Operating costs (1,673) (1,639) 2
Depreciation and amortisation (105) (86) 22
Operating profit - actual exchange rate 169 129 31
Operating profit - constant currency 169 160 6
Operating profit by principal activities Six months ended 30 September
(£m, at constant currency) 2009 2008 % change
Electricity distribution 109 135 (19)
Long Island transmission and distribution 25 9 178

services
Long Island generation 35 16 119
Operating profit 169 160 6
Capital investment Six months ended 30 September
(£m, at actual exchange rate) 2009 2008 % change
Electricity distribution 148 130 14
Long Island generation 18 13 38
Capital investment 166 143 16

During the period, operating profit from Electricity Distribution and Generation increased by 31% to £169m. This period saw an increase in our net revenues of £29m, primarily reflecting the increase in generation contract revenues. Timing related items, mainly relating to an under recovery of income, temporarily reduced operating profit by £64m. Other items, including a reduction in service penalty costs and the absence of non-cash one off items incurred last year, increased operating profit by £44m. 2008 saw us delivering a significant improvement in our upstate New York system reliability performance, consistently beating our historic average and avoiding service penalties. The period on period movement in exchange rates benefited operating profit by £31m.

We have made solid regulatory progress during the period. As planned in Massachusetts and Rhode Island we filed electric rate cases on 15 May 2009 and 1 June 2009 respectively. These filings will benefit both customers and shareholders by supporting much needed investment and recovery of costs. We expect a conclusion to be reached around the end of the year in Massachusetts and early next year in Rhode Island.

Summary results Six months ended 30 September
(£m) 2009 2008 % change
Revenue and other operating income 382 356 7
Operating costs (206) (194) 6
Depreciation and amortisation (86) (77) 12
Operating profit 90 85 6

Operating profit by principal activities Six months ended 30 September
(£m, at actual exchange rate) 2009 2008 % change
Metering 86 76 13
Grain LNG 20 4 400
Property 10 24 (58)
Sub-total operating profit 116 104 12
Corporate and other activities (26) (19) 37
Operating profit 90 85 6
Capital investment* Six months ended 30 September
(£m, at actual exchange rate) 2009 2008 % change
Metering 64 76 (16)
Grain LNG 60 122 (51)
Property 2 3 (33)
Other 13 43 (70)
Capital investment 139 244 (43)

Operating profit from our non-regulated and other activities increased by 6% to £90m. This was primarily driven by an increase in profit in our Metering and Grain LNG businesses, partially offset by a reduction in operating profit in our Property business. As reported in February, given current market conditions we have taken action to defer property sales in order to preserve value. This has reduced operating profit by £14m compared to the previous period.

Metering operating profit was up £10m at £86m, mainly driven by increased revenue, and lower costs and depreciation charges. During the period, capital investment in this business was £64m, with around 360,000 new meters installed. On 29 April 2009 the Competition Appeal Tribunal in part overturned Ofgem's decision to fine us for a breach of the UK Competition Act 1998 and reduced the fine to £30m but also upheld the original decision in part. The Court of Appeal has granted us leave to appeal the Tribunal's decision both on points of law and as to the amount of the penalty.

Our Grain LNG business delivered an operating profit of £20m, five times that of the previous period, as a result of Phase II becoming operational in December 2008. During the period capital investment in this business decreased by 51% to £60m, mainly reflecting the completion of the Phase II capacity extension in October 2008. Phase III is currently under construction and is planned to complete in late 2010. This will add a further LNG tank and a second unloading jetty, increasing the total annual capacity of the terminal to around 15 million tonnes, representing around 20% of total UK gas demand. These investments are underpinned by long-term, take-or-pay contracts, which deliver an index-linked revenue stream for 20 years.

2 December 2009 Ordinary shares go ex-dividend
4 December 2009 Record date for 2009/10 interim dividend
9 December 2009 Scrip reference price announced

18 December 2009 Scrip election date for 2009/10 interim dividend

20 January 2010 2009/10 interim dividend paid to qualifying ordinary
shareholders
February 2010 Interim Management Statement
20 May 2010 2009/10 preliminary results
2 June 2010 Ordinary shares go ex-dividend
4 June 2010 Record date for 2009/10 final dividend
9 June 2010 Scrip reference price announced
Mid-June 2010 Annual Report published
21 July 2010 Scrip election date for 2009/10 final dividend
26 July 2010 Interim Management Statement and
Annual General Meeting, ICC, Birmingham
18 August 2010 2009/10 final dividend paid to qualifying ordinary
shareholders

National Grid:

Investors
David Rees +44 (0)20 7004 3170 +44 (0)7901 511322(m)
George Laskaris +1 718 403 2526 +1 917 375 0989(m)
Richard Smith +44 (0)20 7004 3172 +44 (0)7747 006321(m)

Victoria Davies +44 (0)20 7004 3171 +44 (0)7771 973447(m)

Media
Clive Hawkins +44 (0)20 7004 3147 +44 (0)7836 357173(m)
Chris Mostyn +1 781 907 1726 +1 347 702 3740(m)
Gemma Stokes +44 (0)1926 65 3555 +44 (0)7974 198333(m)

Brunswick: Tom Burns +44 (0)20 7404 5959 +44 (0)7974 982308(m)

An analyst presentation will be held at the London Stock Exchange, 10 Paternoster Square, London EC4M 7LS at 9:15am (UK time) today.

Live telephone coverage of the analyst presentation - password 'National Grid' UK dial in number +44 (0) 203 023 4488 US dial in number +1 866 966 5335

Telephone replay of the analyst presentation (available until 19 December 2009) Dial in number +44 (0) 208 196 1998 Account number 5254788¿

A live web cast of the presentation will also be available at www.nationalgrid.com.

A short video of Steve Holliday talking about these results is available on www.cantos.com.

You can view or download copies of our latest Annual Report or the Annual Review from our website at www.nationalgrid.com/corporate/Investor+Relations/ or request a free printed copy by contacting investor.relations@ngrid.com.

CAUTIONARY STATEMENT

This announcement contains certain statements that are neither reported financial results nor other historical information. These statements are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. These statements include information with respect to National Grid's financial condition, results of operations and businesses, strategy, plans and objectives. Words such as "anticipates", "expects", "intends", "plans", "believes", "seeks", "estimates", "may", "will", "continue", "project" and similar expressions, as well as statements in the future tense, identify forward-looking statements. These forward-looking statements are not guarantees of National Grid's future performance and are subject to assumptions, risks and uncertainties that could cause actual future results to differ materially from those expressed in or implied by such forward-looking statements. Many of these assumptions, risks and uncertainties relate to factors that are beyond National Grid's ability to control or estimate precisely, such as delays in obtaining, or adverse conditions contained in, regulatory approvals and contractual consents, unseasonable weather affecting the demand for electricity and gas, competition and industry restructuring, changes in economic conditions, currency fluctuations, changes in interest and tax rates, changes in energy market prices, changes in historical weather patterns, changes in laws, regulations or regulatory policies, developments in legal or public policy doctrines, the impact of changes to accounting standards, technological developments and the ability to access capital markets and other sources of credit in a timely manner on acceptable terms, especially considering the recent deterioration of market conditions in the global economy and financial markets. Other factors that could cause actual results to differ materially from those described in this announcement include the ability to integrate the businesses relating to announced or recently completed acquisitions with National Grid's existing business to realise the expected synergies from such integration, the availability of new acquisition opportunities and the timing and success of future acquisition opportunities, the timing and success or other impact of the sales of National Grid's non-core businesses, the failure for any reason to achieve reductions in costs or to achieve operational efficiencies, the failure to retain key management, the behaviour of UK electricity market participants on system balancing, the timing of amendments in prices to shippers in the UK gas market, the performance of National Grid's pension schemes and the regulatory treatment of pension costs, and any adverse consequences arising from outages on or otherwise affecting energy networks, including gas pipelines owned or operated by National Grid. For a more detailed description of some of these assumptions, risks and uncertainties, together with any other risk factors, please see National Grid's filings with and submissions to the US Securities and Exchange Commission (the "SEC") (and in particular the "Risk Factors" and "Operating and Financial Review" sections in its most recent Annual Report on Form 20-F). Except as may be required by law or regulation, National Grid undertakes no obligation to update any of its forward-looking statements. The effects of these factors are difficult to predict. New factors emerge from time to time and National Grid cannot assess the potential impact of any such factor on its activities or the extent to which any factor, or combination of factors, may cause results to differ materially from those contained in any forward-looking statement. The contents of any website referenced herein do not form part of this document.

CONSOLIDATED INCOME STATEMENT 2009 2008 Year ended 31 March
for the six months ended 30 2009

September
Notes £m £m £m

Revenue 2a 6,044 6,072 15,624
Other operating income 13 29 63
Operating costs (4,653) (5,158) (13,064)

Operating profit

Interest income and similar 4 509 640 1,315

income Interest expense and other finance costs

Share of post-tax results of 4 3 5

joint ventures and associates Profit before taxation

Taxation

Profit from continuing operations after taxation

continuing operations Profit for the period from discontinued operations

Profit for the period 698 425 947

Attributable to:

Earnings per share from continuing operations*

paid during the period
Dividends per ordinary share: 13.65p 12.64p 35.64p

for the period

for the six months ended 30 September
£m £m £m

Profit for the period 698 425 947

Other comprehensive income:
Exchange adjustments (79) 141 464
Actuarial net loss (1,424) (113) (2,018)
Deferred tax on actuarial net 455 29 678

losses
Net losses taken to equity in (3) (12) (1)

respect of cash flow hedges
Transferred to profit or loss (5) 3 (53)

on cash flow hedges
Deferred tax on cash flow 1 3 19

hedges
Net gains/(losses) taken to 33 (7) 9

equity on available-for-sale investments
Transferred to profit or loss - (2) (18)

on sale of available-for-sale investments
Deferred tax on (5) 1 7

available-for-sale investments
Other comprehensive (1,027) 43 (913)

(loss)/income for the period
Total comprehensive (329) 468 34

(loss)/income for the period Total comprehensive (loss)/income attributable to:

CONSOLIDATED BALANCE SHEET 2009 2008 At 31 March 2009

at 30 September
Notes £m £m £m

Non-current assets
Goodwill 4,843 4,357 5,391
Other intangible assets 355 314 370
Property, plant and equipment 29,197 26,321 29,545
Deferred tax assets 219 - 137
Pension asset - 1,055 269
Other non-current assets 139 128 106
Financial and other 425 304 361

investments
Derivative financial assets 9 1,867 633 1,533

Total non-current assets 37,045 33,112 37,712

Current assets
Inventories and current 647 860 556

intangible assets
Trade and other receivables 1,702 2,085 2,672
Financial and other 9 1,669 1,265 2,197

investments
Derivative financial assets 9 432 291 593
Cash and cash equivalents 9 359 148 737

Total current assets 4,809 4,649 6,755

Total assets 2d 41,854 37,761 44,467

Current liabilities
Borrowings 9 (2,626) (2,412) (3,253)
Derivative financial 9 (183) (317) (307)

liabilities
Trade and other payables (2,302) (2,391) (2,835)
Current tax liabilities (274) (642) (383)
Provisions (263) (291) (248)

Total current liabilities (5,648) (6,053) (7,026)

Non-current liabilities
Borrowings 9 (22,883) (19,092) (23,540)
Derivative financial 9 (615) (272) (633)

liabilities
Other non-current liabilities (1,936) (1,948) (2,092)
Deferred tax liabilities (2,514) (2,883) (2,661)
Pensions and other (3,652) (1,664) (3,080)

post-retirement benefit obligations
Provisions (1,349) (1,124) (1,451)

Total non-current liabilities (32,949) (26,983) (33,457)

Total liabilities (38,597) (33,036) (40,483)

Net assets 3,257 4,725 3,984

Equity
Called up share capital 297 294 294
Share premium account 1,368 1,371 1,371
Retained earnings 6,467 8,171 7,135
Other equity reserves (4,887) (5,124) (4,830)

Shareholders' equity 3,245 4,712 3,970
Minority interests 12 13 14

Total equity 3,257 4,725 3,984

CONSOLIDATED STATEMENT OF Called-up share Share premium Retained earnings Other equity Total share-holders' Minority interests Total equity
CHANGES IN EQUITY capital account reserves equity
£m £m £m £m £m £m £m

Changes in equity for the period:

At 1 April 2009 294 1,371 7,135 (4,830) 3,970 14 3,984
Total comprehensive - - (273) (57) (330) 1 (329)

(loss)/income for the period
Equity dividends - - (557) - (557) - (557)
Scrip dividend related share 3 (3) 137 - 137 - 137

issue
Other movements in minority - - - - - (3) (3)

interests
Share-based payment - - 10 - 10 - 10
Issue of treasury shares - - 13 - 13 - 13
Tax on share-based payment - - 2 - 2 - 2
At 30 September 2009 297 1,368 6,467 (4,887) 3,245 12 3,257
Called-up share Share premium Retained earnings Other equity Total share-holders' Minority interests Total equity
capital account reserves equity
£m £m £m £m £m £m £m

Changes in equity for the period:

At 1 April 2008 294 1,371 8,943 (5,252) 5,356 18 5,374
Total comprehensive income for - - 338 128 466 2 468

the period
Equity dividends - - (531) - (531) - (531)
Repurchase of share capital - - (599) - (599) - (599)

and purchase of treasury shares
Other movements in minority - - - - - (7) (7)

interests
Share-based payment - - 10 - 10 - 10
Issue of treasury shares - - 8 - 8 - 8
Tax on share-based payment - - 2 - 2 - 2
At 30 September 2008 294 1,371 8,171 (5,124) 4,712 13 4,725
Called-up share Share premium Retained earnings Other equity Total share-holders' Minority interests Total equity
capital account reserves equity
£m £m £m £m £m £m £m

Changes in equity for the year:

At 1 April 2008 294 1,371 8,943 (5,252) 5,356 18 5,374
Total comprehensive - - (396) 422 26 8 34

(loss)/income for the year
Equity dividends - - (838) - (838) - (838)
Repurchase of share capital - - (603) - (603) - (603)

and purchase of treasury shares
Other movements in minority - - - - - (12) (12)

interests
Share-based payment - - 22 - 22 - 22
Issue of treasury shares - - 8 - 8 - 8
Tax on share-based payment - - (1) - (1) - (1)
At 31 March 2009 294 1,371 7,135 (4,830) 3,970 14 3,984
CONSOLIDATED CASH FLOW 2009 2008 Year ended 31 March

for the six months ended 30 September
£m £m £m

Cash flows from operating activities
Total operating profit 1,404 943 2,623

Adjustments for:
Exceptional items, (255) 136 292

remeasurements and stranded cost recoveries
Depreciation and amortisation 585 511 1,122
Share-based payment charge 10 10 22
Changes in working capital 329 (161) 54
Changes in provisions (57) (32) (99)
Changes in pensions and other (409) (547) (678)

post-retirement benefit obligations
Cash flows relating to (72) (39) (131)

exceptional items
Cash flows relating to 194 113 359

stranded cost recoveries
Cash flows generated from 1,729 934 3,564

continuing operations
Cash flows relating to - 1 (8)

discontinued operations (excluding tax)
Cash generated from operations 1,729 935 3,556
Tax paid (131) (229) (143)

Net cash inflow from operating 1,598 706 3,413

activities Cash flows from investing activities
Acquisition of investments (53) (29) (73)
Purchases of intangible assets (35) (56) (78)
Purchases of property, plant (1,426) (1,535) (3,107)

and equipment
Disposals of property, plant 9 18 27

and equipment
Interest received 12 61 85
Dividends received from joint 17 - -

ventures
Net movements in financial 507 814 99

investments
Cash flows used in continuing (969) (727) (3,047)

operations - investing activities Cash flows relating to discontinued operations

investing activities Cash flows from financing activities
Proceeds from issue of share 13 8 8

capital and sale of treasury shares
(Decrease)/increase in (112) 17 1,641

borrowings and related derivatives
Interest paid (480) (468) (1,061)
Dividends paid to shareholders (420) (531) (838)
Repurchase of share capital - (623) (627)

and purchase of treasury shares
Net cash flow used in (999) (1,597) (877)

financing activities
Net (decrease)/increase in (370) (21) 538

cash and cash equivalents
Exchange movements (7) 5 18
Net cash and cash equivalents 720 164 164

at start of period
Net cash and cash equivalents 343 148 720

at end of period (ii)

1. Basis of preparation and new accounting standards, interpretations and amendments

The half year financial information covers the six month period ended 30 September 2009 and has been prepared under International Financial Reporting Standards (IFRS) as issued by the International Accounting Standards Board (IASB), and IFRS as adopted by the European Union, in accordance with International Accounting Standard 34 'Interim Financial Reporting' and the Disclosure and Transparency Rules of the Financial Services Authority. The half year financial information is unaudited but has been reviewed by the auditors and their report is attached to this document.

The following standards, interpretations and amendments, issued by the IASB and by the International Financial Reporting Interpretations Committee (IFRIC), are effective for the year ending 31 March 2010. None of these had a material impact on consolidated results or assets and liabilities.

The following interpretation and amendments, issued by the IFRIC and the IASB, are effective for the year ending 31 March 2010, but have not yet been endorsed by the European Union:

The amendment to IFRS 7 and amendments to IFRIC 9 and IAS 39 have no impact on the consolidated results or assets and liabilities of the Company. The impact of IFRIC 18 is to increase profit for the six months ended 30 September 2009 and reduce liabilities as at 30 September 2009; however, the adoption of this interpretation did not have a material impact on our consolidated results or assets and liabilities and therefore the half year financial information complies with both IFRS as issued by the IASB and IFRS as adopted by the European Union.

The half year financial information does not constitute statutory accounts as defined in Section 434 of the Companies Act 2006. It should be read in conjunction with the statutory accounts for the year ended 31 March 2009, which were prepared in accordance with IFRS as adopted by the European Union and the IASB and have been filed with the Registrar of Companies. The auditors' report on these statutory accounts was unqualified and did not contain a statement under Section 237(2) or (3) of the Companies Act 1985.

The half year financial information has been prepared in accordance with the accounting policies expected to be applicable for the year ending 31 March 2010 and consistent with those applied in the preparation of our accounts for the year ended 31 March 2009, except for the impact of new standards, interpretations and amendments noted above.

Date of approval

This announcement was approved by the Board of Directors on 18 November 2009.
2. Segmental analysis

The segmental analysis is based on the information the Board of Directors uses internally for the purposes of evaluating the performance of operating segments and determining resource allocation between operating segments. The Company assesses the performance of its operations principally on the basis of operating profit before exceptional items, remeasurements and stranded cost recoveries. The following table describes the main activities for each operating segment:

Transmission UK High-voltage electricity transmission networks, the gas
transmission network in the UK, UK liquefied natural gas (LNG)
storage activities and the French electricity interconnector.
Transmission US High-voltage electricity transmission networks in New York and
New England.
Gas Distribution UK Four of the eight regional networks of Great Britain's gas
distribution system.
Gas Distribution US Gas distribution in New York and New England.
Electricity Distribution and Electricity distribution in New York and New England and
Generation US electricity generation in New York.

Other activities primarily relate to non-regulated businesses and other commercial operations not included within the above segments, including: UK-based gas metering activities; UK property management; a UK LNG import terminal; other LNG operations; US unregulated transmission pipelines; US gas fields; and corporate activities, including business development.

Sales between operating segments are priced having regard to the regulatory and legal requirements to which the businesses are subject.

The Gas Distribution US segment experiences significant seasonal fluctuations owing to weather conditions and peak delivery volumes occurring in the second half of the fiscal year. In the UK the pricing methodology for gas distribution has a higher capacity delivery component and a lower volume component and so is not subject to such significant seasonal fluctuations.

A reconciliation of the operating segments' measure of profit to total profit before taxation is provided on the face of the income statement. Further details of the reconciling items are provided in note 3.

Operating segments - continuing operations
Transmission UK 1,609 1,799 3,487
Transmission US 208 176 420
Gas Distribution UK 768 647 1,466
Gas Distribution US 999 1,216 4,786
Electricity Distribution and 2,175 2,011 4,972

Generation US
Other activities 378 327 719
Sales between operating segments (93) (104) (226)
Revenue 6,044 6,072 15,624
Total excluding stranded cost 5,816 5,915 15,189

recoveries
Stranded cost recoveries 228 157 435
Revenue 6,044 6,072 15,624

Geographical area
UK 2,695 2,666 5,334
US 3,349 3,406 10,290
Revenue 6,044 6,072 15,624
2. Segmental analysis (continued)

£m £m £m

Operating segments - continuing operations
Transmission UK 549 508 1,126
Transmission US 88 83 175
Gas Distribution UK 385 264 672
Gas Distribution US (132) 10 612
Electricity Distribution and Generation 169 129 265

Other activities 90 85 65
Operating profit before exceptional items, 1,149 1,079 2,915

remeasurements and stranded cost recoveries

Geographical area
UK 1,022 855 1,875
US 127 224 1,040
Operating profit before exceptional items, 1,149 1,079 2,915

remeasurements and stranded cost recoveries

c) Operating profit - after exceptional items, remeasurements and stranded cost recoveries
Six months ended 30 September 2009 2008 Year ended 31 March

£m £m £m

Operating segments - continuing operations
Transmission UK 544 503 1,063
Transmission US 86 82 173
Gas Distribution UK 378 251 629
Gas Distribution US (47) (205) 226
Electricity Distribution and 356 232 531

Generation US
Other activities 87 80 1
Operating profit after exceptional 1,404 943 2,623

items, remeasurements and stranded cost recoveries

Geographical area
UK 1,010 843 1,729

Operating profit after exceptional 1,404 943 2,623

items, remeasurements and stranded cost recoveries

2. Segmental analysis (continued)

d) Total assets
As at 30 September 2009 2008 31 March 2009
£m £m £m

Operating segments - continuing operations
Transmission UK 10,552 10,948 10,451
Transmission US 2,229 1,906 2,238
Gas Distribution UK 6,393 6,035 6,158
Gas Distribution US 8,736 7,936 10,112
Electricity Distribution and Generation US 6,629 6,042 7,854
Other activities 2,547 2,446 2,289
37,086 35,313 39,102
Joint ventures - continuing operations 222 111 168
Unallocated 4,546 2,337 5,197
Total assets 41,854 37,761 44,467

Geographical area
UK 18,976 18,859 18,527
US 18,332 16,565 20,743
Unallocated 4,546 2,337 5,197
Total assets 41,854 37,761 44,467

The analysis of total assets includes all attributable goodwill and excludes inter-segment balances. Unallocated total assets comprise cash and cash equivalents, taxation, current financial investments and total derivative financial assets.

e) Depreciation and amortisation
Six months ended 30 September 2009 2008 Year ended
31 March 2009
£m £m £m

Operating segments - continuing operations
Transmission UK 182 174 353
Transmission US 29 22 56
Gas Distribution UK 96 86 177
Gas Distribution US 87 71 172
Electricity Distribution and Generation US 108 86 223
Other activities 86 77 146
Depreciation and amortisation* 588 516 1,127

Geographical area

Depreciation and amortisation* 588 516 1,127

Exceptional items, remeasurements and stranded cost recoveries are items of income and expenditure that, in the judgement of management, should be disclosed separately on the basis that they are material, either by their nature or their size, to an understanding of our financial performance and significantly distort the comparability of financial performance between periods. Items of income or expense that are considered by management for designation as exceptional items include such items as significant restructurings, write-downs or impairments of non-current assets, material changes in environmental or decommissioning provisions, integration of acquired businesses, amortisation of acquisition-related intangibles and gains or losses on disposals of businesses or investments.

Remeasurements comprise gains or losses recorded in the income statement arising from changes in the fair value of commodity contracts and of derivative financial instruments to the extent that hedge accounting is not achieved or is not effective.

Stranded cost recoveries represent the recovery of historical costs in the US related to generation assets that are no longer owned. Such costs can be recovered from customers as permitted by regulatory agreements.
Six months ended 30 September 2009 2008
Year ended 31 March

£m £m £m
Exceptional items - restructuring costs (48) (39) (192)

(i)
Exceptional items - environmental related (7) (9) (78)

provisions (ii)
Exceptional items - other (iii) (3) (3) (5)
Remeasurements - commodity contracts (iv) 113 (239) (443)
Stranded cost recoveries (v) 200 154 426
Total exceptional items, remeasurements 255 (136) (292)

and stranded cost recoveries included within operating profit

Remeasurements - commodity contracts (iv) (1) 2 (2)
Remeasurements - net gains/(losses) on 41 140 (82)

derivative financial instruments (vi)
Total exceptional items and remeasurements 40 142 (84)

included within finance costs

Total exceptional items, remeasurements 295 6 (376)

and stranded cost recoveries before taxation

Exceptional tax item - deferred tax charge - (40) (49)

arising from change in UK industrial building allowance regime (vii)
Tax on exceptional items - restructuring 17 13 59

costs (i)
Tax on exceptional items - environmental 3 4 16

related provisions (ii)
Tax on exceptional items - other (iii) 1 1 2
Tax on remeasurements - commodity (45) 94 179

contracts (iv)
Tax on remeasurements - derivative (49) (42) 8

financial instruments (vi)
Tax on stranded cost recoveries (v) (80) (61) (170)
Tax on exceptional items, remeasurements (153) (31) 45

and stranded cost recoveries

Total exceptional items, remeasurements 142 (25) (331)

and stranded cost recoveries

Total exceptional items after taxation (37) (73) (247)
Total commodity contract remeasurements 67 (143) (266)

after taxation
Total derivative financial instrument (8) 98 (74)

remeasurements after taxation
Total stranded cost recoveries after 120 93 256

taxation

Total exceptional items, remeasurements 142 (25) (331)

and stranded cost recoveries after taxation

3. Exceptional items, remeasurements and stranded cost recoveries (continued)

4. Finance income and costs

Six months ended 30 September 2009 2008
Year ended 31 March

£m £m £m
Interest income on financial 12 54 79

instruments
Expected return on pension and 497 586 1,236

other post-retirement benefit plan assets (i)

Interest income and similar 509 640 1,315

income

Interest expense on financial (421) (621) (1,280)

instruments
Interest on pension and other (603) (588) (1,250)

post-retirement benefit plan liabilities
Unwinding of discounts on (39) (26) (68)

provisions
Less: interest capitalised 50 71 133
Interest expense (1,013) (1,164) (2,465)

Net gains/(losses) on derivative financial instruments and commodity contracts
included in remeasurements 40 142 (84)
Interest expense and other (973) (1,022) (2,549)

finance costs

Net finance costs (464) (382) (1,234)

Comprising:
Net finance costs excluding (504) (524) (1,150)

exceptional finance costs and remeasurements
Exceptional items and 40 142 (84)

remeasurements (see note 3)

(464) (382) (1,234)

i) The difference between actual and expected investment return on pension assets is reported as an actuarial gain or loss within the statement of comprehensive income.

5. Taxation

The tax charge for the period, excluding tax on exceptional items, remeasurements and stranded cost recoveries is £93m (six months ended 30 September 2008: £125m; year ended 31 March 2009: £517m). The effective tax rate of 14.3% (six months ended 30 September 2008: 22.4%) for the period is based on the best estimate of the weighted average annual income tax rate by jurisdiction expected for the full year. The current period rate reflects the seasonality of earnings following the KeySpan acquisition as well as other discrete items. For the full year we expect the group effective tax rate to be approximately 29%. The actual effective tax rate for the year ended 31 March 2009 was 29.2%.

6. Earnings per share

a) Basic earnings per share
Six months ended 30 September Year ended 31 March Year ended 31 March

Earnings Earnings Earnings Earnings per share Earnings
per share Earnings per share
£m pence £m pence* £m pence*
Adjusted - continuing 554 22.5 431 17.2 1,250 50.4

operations
Exceptional items after (37) (1.5) (73) (2.9) (247) (10.0)

taxation
Commodity contract 67 2.7 (143) (5.7) (266) (10.7)

remeasurements after taxation
Derivative remeasurements (8) (0.3) 98 3.9 (74) (2.9)

after taxation
Stranded cost recoveries after 120 4.9 93 3.7 256 10.3

taxation

Continuing operations 696 28.3 406 16.2 919 37.1
Adjusted - discontinued - - 6 0.2 9 0.4

operations
Gains on disposal of - - 11 0.4 16 0.6

operations after taxation

Discontinued operations - - 17 0.6 25 1.0
Basic 696 28.3 423 16.8 944 38.1
millions millions* millions*
Weighted average number of 2,458 2,506 2,480

shares - basic

b) Diluted earnings per share
Six months ended 30 September Year ended 31 March Year ended 31 March

Earnings Earnings Earnings Earnings Earnings
per share per share Earnings per share
£m pence £m pence* £m pence*
Adjusted diluted - continuing 554 22.4 431 17.1 1,250 50.1

operations
Exceptional items after (37) (1.5) (73) (2.9) (247) (9.9)

taxation
Commodity contract 67 2.7 (143) (5.7) (266) (10.7)

remeasurements after taxation
Derivative remeasurements (8) (0.3) 98 3.9 (74) (3.0)

after taxation
Stranded cost recoveries after 120 4.8 93 3.7 256 10.3

taxation

Diluted - continuing 696 28.1 406 16.1 919 36.8

operations

Adjusted diluted - - - 6 0.2 9 0.4

discontinued operations
Gains on disposal of - - 11 0.4 16 0.6

operations after taxation

Diluted - discontinued - - 17 0.6 25 1.0

operations

Diluted 696 28.1 423 16.7 944 37.8
millions millions* millions*
Weighted average number of 2,473 2,523 2,497

shares - diluted

7. Dividends

The following table shows the dividends paid to equity shareholders:
Six months ended 30 September 2009 2009 2009 2008 2008 Year ended Year
31 March 2009 ended
31 March 2009
pence Total pence Total pence Total
per share £m Settled per share £m per share £m
via scrip
£m

Ordinary dividends
Final - year ended 31 March - - - 21.30 531 21.30 531

Interim - year ended 31 March - - - - - 12.64 307

Final - year ended 31 March 23.00 557 137 - - - -

23.00 557 137 21.30 531 33.94 838

The Directors are proposing an interim dividend of 13.65p per share that would absorb approximately £336m of shareholders' equity to be paid in respect of the year ending 31 March 2010. A scrip dividend will be offered as an alternative.

8. Reconciliation of net cash flow to movement in net debt

Six months ended 30 September 2009 2008
Year ended 31 March

£m £m £m
(Decrease)/ increase in cash (370) (21) 538

and cash equivalents
Decrease in financial (507) (814) (99)

investments
Decrease/(increase) in 112 (17) (1,641)

borrowings and related derivatives (i)
Net interest paid on the 468 407 956

components of net debt

Increase in net debt resulting (297) (445) (246)

from cash flows
Changes in fair value of 1,404 (1,103) (3,625)

financial assets and liabilities and exchange movements
Net interest charge on the (414) (567) (1,161)

components of net debt

Movement in net debt (net of 693 (2,115) (5,032)

related derivative financial instruments) in the period
Net debt (net of related (22,673) (17,641) (17,641)

derivative financial instruments) at start of period

Net debt (net of related (21,980) (19,756) (22,673)

derivative financial instruments) at end of period

i) The decrease in borrowings and related derivatives for the six months ended 30 September 2009 comprises proceeds received from loans issued of £0.9bn less payments to repay loans of £0.7bn and movement in short-term borrowings and derivative settlements of £0.3bn.

9. Net debt

At 30 September 2009 2008
31 March

£m £m £m
Cash and cash equivalents 359 148 737
Bank overdrafts (16) - (17)
Net cash and cash equivalents 343 148 720
Financial investments 1,669 1,265 2,197
Borrowings (excluding bank overdrafts) (25,493) (21,504) (26,776)
(23,481) (20,091) (23,859)
Net debt related derivative financial assets 2,299 924 2,126
Net debt related derivative financial (798) (589) (940)

liabilities

Net debt (net of related derivative financial (21,980) (19,756) (22,673)

instruments)

10. Commitments and contingencies
At 30 September 2009 2008 31 March

£m £m £m
Future capital expenditure contracted for but not 1,698 1,286 1,626

provided
Commitments under non-cancellable operating leases 841 818 946
Energy purchase commitments (i) 3,488 2,766 3,645
Guarantees (ii) 1,196 970 1,202
Other commitments and contingencies (iii) 670 246 644

Comparatives have been restated to present items on a basis consistent with the current period classification.

i) Commodity contracts that do not meet the normal purchase, sale or usage criteria and hence are accounted for as derivative contracts are recorded at fair value and incorporated in other non-current assets, trade and other receivables, trade and other payables and other non-current liabilities. At 30 September 2009 these amounted to £196m (30 September 2008: £64m; 31 March 2009: £310m).

ii) Details of the guarantees entered into by the Company or its subsidiary undertakings at 30 September 2009 are shown below:

iii) Includes commitments largely relating to gas purchasing and property remediation of £640m (30 September 2008: £195m; 31 March 2009: £615m).

In last year's Annual Report and Accounts we reported a decision by the Gas and Electricity Markets Authority (GEMA) (the "Decision") to levy on us a fine of £41.6 million for a breach of the UK Competition Act 1998 in respect of term contracts with gas suppliers entered into by our UK metering services business in 2004. We also noted that we had appealed the Decision to the Competition Appeal Tribunal (the "Tribunal"). On 29 April 2009, the Tribunal overturned the Decision in part and reduced the fine to £30 million but upheld the original Decision in part. The Court of Appeal has granted us leave to appeal the Tribunal's decision both on points of law and as to the amount of the penalty.

As at the date of this announcement, we remain of the view that an outflow of economic benefits is not probable, and as a result, no provision has been made in these accounts either for the reduced fine of £30 million, or for any other possible financial impact of the ruling.

In October 2008, we informed Ofgem that our mains replacement activity carried out within the UK's West Midlands Alliance partnership may have been misreported. National Grid and Ofgem jointly appointed Ernst & Young to carry out a full investigation to determine the extent of the issue. At present it is too early to determine the likely outcome of the investigation and any potential consequences.

In May 2007, KeySpan received a civil investigative demand from the Antitrust Division of the United States Department of Justice (DoJ), requesting the production of documents and information relating to its investigation of competitive issues in the New York City electricity capacity market prior to the Company's acquisition of KeySpan. The civil investigative demand is a request for information in the course of an investigation and does not constitute the commencement of legal proceedings, and no specific allegations have been made against KeySpan. In April 2008, KeySpan received a second civil investigative demand in connection with this matter. KeySpan believes that its activity in the capacity market has been consistent with all applicable laws and regulations and it continues to cooperate fully with the investigation. Since July 2009, KeySpan and the DoJ have entered discussions that could potentially lead to a settlement of this matter.

11. Exchange rates

The consolidated results are affected by the exchange rates used to translate the results of its US operations and US dollar transactions. The US dollar to pound sterling exchange rates used were:
30 September 2009 2008
Year ended 31 March

Closing rate applied at period end 1.60 1.78 1.44
Average rate applied for the period 1.55 1.92 1.54

12. Related party transactions

There were no significant changes in the nature and size of related party transactions for the period to those disclosed in the financial statements for the year ended 31 March 2009.

13. Principal risks and uncertainties

The principal risks and uncertainties which could affect National Grid for the remaining six months of the financial year are disclosed in the Annual Report and Accounts 2008/09 ('Annual Report'). A list of the significant risks is provided on page 40 of the Annual Report, and the risks are then disclosed in more detail on pages 97 to 99, and pages 166 to 172. Our overall risk management process is designed to identify, manage, and mitigate our business risks, including financial risks. Our assessment of the principal risks and uncertainties and our risk management processes have not changed since the year end.

Statement of Directors' Responsibilities

The half year report is the responsibility of, and has been approved by, the Directors. The Directors are responsible for preparing the half year report in accordance with the Disclosure and Transparency Rules of the United Kingdom's Financial Services Authority.

The Directors confirm that the financial information has been prepared in accordance with IAS 34 as adopted by the European Union, and that the half year report herein includes a fair review of the information required by DTR 4.2.7 and DTR 4.2.8.

The Directors of National Grid plc are as listed in the National Grid plc Annual Report for the year ended 31 March 2009 with the exception of Bob Catell who retired from the Board on 27 July 2009.

By order of the Board

Steve Holliday Steve Lucas
18 November 2009 18 November 2009
Chief Executive Officer Finance Director

Independent review report to National Grid plc

Introduction

We have been engaged by the Company to review the condensed set of financial statements in the half-yearly financial report for the six months ended 30 September 2009, which comprises the consolidated income statement, statement of comprehensive income, balance sheet, statement of changes in equity, cash flow statement and related notes. We have read the other information contained in the half-yearly financial report and considered whether it contains any apparent misstatements or material inconsistencies with the information in the condensed set of financial statements.

Directors' responsibilities

The half-yearly financial report is the responsibility of, and has been approved by, the directors. The directors are responsible for preparing the half-yearly financial report in accordance with the Disclosure and Transparency Rules of the United Kingdom's Financial Services Authority.

As disclosed in note 1, the annual financial statements of the group are prepared in accordance with International Financial Reporting Standards (IFRSs) as adopted by the European Union. The condensed set of financial statements included in this half-yearly financial report has been prepared in accordance with International Accounting Standard 34, 'Interim Financial Reporting', as adopted by the European Union.

Our responsibility

Our responsibility is to express to the company a conclusion on the condensed set of financial statements in the half-yearly financial report based on our review. This report, including the conclusion, has been prepared for and only for the company for the purpose of the Disclosure and Transparency Rules of the Financial Services Authority and for no other purpose. We do not, in producing this report, accept or assume responsibility for any other purpose or to any other person to whom this report is shown or into whose hands it may come save where expressly agreed by our prior consent in writing.

Scope of review

We conducted our review in accordance with International Standard on Review Engagements (UK and Ireland) 2410, 'Review of Interim Financial Information Performed by the Independent Auditor of the Entity' issued by the Auditing Practices Board for use in the United Kingdom. A review of interim financial information consists of making enquiries, primarily of persons responsible for financial and accounting matters, and applying analytical and other review procedures. A review is substantially less in scope than an audit conducted in accordance with International Standards on Auditing (UK and Ireland) and consequently does not enable us to obtain assurance that we would become aware of all significant matters that might be identified in an audit. Accordingly, we do not express an audit opinion.

Conclusion

Based on our review, nothing has come to our attention that causes us to believe that the condensed set of financial statements in the half-yearly financial report for the six months ended 30 September 2009 is not prepared, in all material respects, in accordance with International Accounting Standard 34 as adopted by the European Union and the Disclosure and Transparency Rules of the United Kingdom's Financial Services Authority.

PricewaterhouseCoopers LLP

Chartered Accountants

London

18 November 2009

<HR>---------------------------------------

1 Business performance results are the primary financial performance measure used by National Grid, being the results for continuing operations before exceptional items, remeasurements and stranded cost recoveries. Remeasurements comprise gains or losses recorded in the income statement arising from changes in the fair value of commodity contracts and of derivative financial instruments to the extent that hedge accounting is not achieved or is not fully effective. Stranded cost recoveries are costs associated with historical generation investment and related contractual commitments that were not recovered through the sale of those investments - these recoveries end in 2011. Further details are provided in Note 3 on page 20. A reconciliation of business performance to statutory results is provided in the consolidated income statement on page 11.

2 Operating cash flow from continuing operations before exceptional items, remeasurements, stranded cost recoveries and taxation.

3 Adjusted to reflect scrip dividend, refer to note 6 on page 22.

4 'Constant currency basis' refers to the reporting of the actual results against the prior period results which, in respect of any US$ currency denominated activity, have been translated using the average US$ exchange rate for the six months ended 30 September 2009, which was $1.55 to £1.00. The average rate for the six months ended 30 September 2008 was $1.92 to £1.00.

This information is provided by RNS The company news service from the London Stock Exchange

IR BVLLFKFBXFBD

((London Equities Newsroom; +44 20 7542 7717)) (For more news, please click here)

COPYRIGHT

Copyright Thomson Reuters 2009. All rights reserved. The copying, republication or redistribution of Reuters News Content, including by framing or similar means, is expressly prohibited without the prior written consent of Thomson Reuters.

Lord Smith of Kelvin, Chairman of SSE, said:

"SSE's focus is always on full-year results, but it is clearly encouraging that financial performance in the first six months is consistent with our goal of a moderate, single digit increase in adjusted profit before tax for the financial year as a whole.

"The unusual and exceptional circumstances that can apply to performance in any six month period are demonstrated by the fact that our half-year adjusted profit before tax shows a marked increase on the exceptionally low level in the same period last year but is still substantially lower than in 2007 and 2006.

"SSE has again delivered sector-leading service to energy supply and electricity distribution customers, added to its operational asset base in electricity generation and gas storage and maintained record levels of investment in the reliability of electricity networks.

"We are now more than 18 months into our five-year, £6.7 billion programme of investment in electricity generation, energy networks and gas storage. While the last six months have again demonstrated the short-term complexities and challenges involved in investment on such a scale, the long-term value of the assets this programme is delivering is not in doubt.

"This investment programme is supported by our carefully-maintained balance sheet, with a successful bond issue in September taking to over £3.3bn the amount of medium- and long-term finance we have secured in the past 18 months.

"Creating value from investment and enhancing value from operations remain central to delivering SSE's goal of sustained annual above-inflation increases in the dividend. Today's 6.1% increase takes our interim dividend to 21 pence per share and means we are on course to deliver a full-year dividend of at least 70 pence per share."

SUMMARY OF KEY ISSUES

Delivering sustained real growth in the dividend

Achieving moderate growth in adjusted profit before tax

Financing for the long term

Expanding Generation portfolio

Growing customer base

Enhancing Regulatory Asset Value for Energy Networks

Developing Energy-Related Services

Purpose and Strategy

SSE's core purpose is to provide the energy people need in a reliable and sustainable way. In line with this, its strategy has been and will continue to be the delivery of sustained real growth in the dividend payable to shareholders through the efficient operation of, and investment in, a balanced range of regulated and non-regulated energy-related businesses. Day-to-day implementation of this strategy continues to be governed by the six key financial principles set out most recently in the Annual Report 2009:

SSE's strategy provides it with three key advantages:

All of this means that SSE is not over-exposed to any particular shorter-term trend or fad within its sector or the wider economy and is in a position to pursue operational, investment or acquisition opportunities throughout the electricity and gas sector to achieve sustained increases in profitability and thereby support sustained real dividend growth.

Future Environment

The UK government published The UK Low Carbon Transition Plan and The UK Renewable Energy Strategy in July 2009, with the stated aim of delivering by 2020 a cut of 18% in greenhouse gas emissions, compared with 2008. This will require around 30% of the electricity consumed in the UK to come from renewable sources by 2020, compared with just 6% at present. The UK government's plan and strategy followed the EU Climate and Energy package, formally agreed in April 2009, which states that 20% of the EU's all-energy consumption must come from renewable sources by 2020.

An increasingly well-recognised benefit of this focus on renewable energy is that it will make a significant contribution to the security of fuel supplies by reducing dependency on oil and gas, as global demand for these increasingly-scarce commodities accelerates. In his report to the UK Department of Energy and Climate Change in August 2009, Energy Security: A national challenge in a changing world, Malcolm Wicks MP said the transition to a low carbon economy 'is a major contributor to our future energy security'.

The UK Low Carbon Transition Plan also reaffirmed the UK government's view that nuclear power is low carbon, affordable, dependable, safe and capable of increasing diversity of energy supply and that new nuclear power stations should have a role to play in the country's future energy mix.

The transition to a low carbon economy will bring other key changes: electricity is likely to become a major transport fuel through electric vehicles; and a much greater proportion of demand for heat is likely to be met from electricity generated from renewable sources.

As energy production changes so, too, will energy consumption. The UK government's decision to mandate the installation of smart meters in every home by the end of 2020 is designed to enable people to understand their energy use, maximise opportunities for energy saving and lead to better services from energy suppliers. This, combined with the major ongoing investment in improving the efficiency with which energy is used, will transform the consumption of gas and electricity in future years.

Implications for SSE

SSE believes that the pace of change in the electricity and gas sectors in the UK, Ireland and elsewhere will increase in the coming years and that the main implications for each of its principal business areas are clear:

Fundamentally, as the UK becomes increasingly dependent on imports of energy and as the need for action to de-carbonise the economy intensifies, the importance and value of efficient energy storage, production, distribution and supply will all increase. This is because, as Ofgem put it in its review of the country's energy supplies in October 2009 'Britain faces a tough challenge in maintaining secure supplies whilst at the same time meeting its climate change targets'. SSE, as the UK's broadest-based energy company, and with significant assets and investments in Generation, Supply, Networks and Services, is in a good position to secure continuing, sustained real dividend growth by helping to meet the needs of energy customers.

Priorities for 2009/10

SSE's priorities for the rest of 2009/10 are straightforward. They are to:

An update on SSE's progress will be provided in its next Interim Management Statement, to be published by 17 February 2010.

Priorities for 2010/11 and Beyond

Longer term, SSE expects to maintain its track record of annual above-inflation increases in the dividend through a combination of value enhancement from operational excellence and value creation from the successful delivery of its key investment opportunities.

Just as SSE's principal goal for shareholders, sustained real dividend growth, is consistent and unchanging, so too are its priorities for 2010/11 and beyond. They are to:

FINANCIAL OVERVIEW

Approach to Financial Results

These financial results for the six months to 30 September 2009 are reported under International Financial Reporting Standards, as adopted by the EU. SSE's focus has consistently been, and remains, on profit before tax before exceptional items, the impact of International Accounting Standards IAS 32 and IAS 39 and after the removal of taxation on profits from jointly controlled entities and associates.

This 'adjusted profit before tax*' was first adopted by SSE in the six months to 30 September 2005. The adjusted definition of profit before tax reflects the underlying profits of its business, reflects the basis on which the business is managed and avoids the volatility introduced by IAS 39. The table below reconciles SSE's reported profit before tax and its adjusted profit before tax*.

SSE has previously stated (most recently in its Annual Report 2009) that its focus is on a full-year, as opposed to half-year, performance and that its six-month financial results in any financial year should always be viewed in light of that. This is for the reason it has set out in the past: six-month results are more likely to fluctuate, with unusual variations or exceptional circumstances.

Sept 09 Sept 08
£m £m
Reported Profit before Tax 514.4 171.1
Movement on derivatives (IAS 39) (118.1) 123.4
Tax on JCEs and Associates 14.2 7.3
Interest on convertible debt - 0.8
Adjusted Profit before Tax* 410.5 302.6
Adjusted current tax charge (94.4) (74.2)
Adjusted Profit after Tax* 316.1 228.4
Reported profit after tax 378.6 127.5
Number of shares for basic and adjusted EPS (million) 920.8 871.4
Adjusted EPS* 34.2 26.3
Basic EPS 41.0 14.7

IAS 39 requires companies to record certain forward commodity contracts that are deemed to be derivative financial instruments at 'fair value'. At 30 September 2009, there was a net derivative financial liability in SSE's balance sheet arising from IAS 39 of £1,239.8m, before tax, compared with a net liability of £1,423.6m, before tax, at 31 March 2009.

The extent of the actual profit or loss arising over the life of the contracts giving rise to this liability will not be determined until they unwind; for around 75% of the total energy volume, this will be over the next 18 months.

The liability principally relates to some of the forward commodity purchase contracts for gas, coal, oil, carbon and wholesale electricity that SSE, like all major energy suppliers, has to enter into to ensure that the future requirements of its customers are met. In recording these contracts at their 'fair value', the prevailing forward market price at 30 September is applied against the actual contract price which, in most cases, was higher than the market price (in other words 'out of the money'). SSE sets out these fair-value movements separately, as re-measurements, as they do not reflect the underlying performance of the business.

Thus, the movement on derivatives under IAS 39 of £118.1m shown in the table above and on the face of the income statement is primarily due to a reduction in the 'out-of-the-money' position on commodity contracts between 31 March 2009 and 30 September 2009.

Adjusted Profit Before Tax* for Six Months to 30 September 2009

Adjusted profit before tax* was £410.5m. This compares with £302.6m in the same six months in 2008. The increase in half-year to half-year profitability followed five key steps forward in SSE's Generation and Supply business in 2009, providing a marked contrast with the same period in 2008:

Nevertheless SSE's gas supply business, Southern Electric Gas, incurred a loss during the period.

Energy supply has also been characterised by falling demand for electricity and gas and by an increase in bad debt in the six months to September 2009.

Adjusted Profit Before Tax* for 2009/10

SSE's emphasis is on adjusted profit before tax* on a full-year, as opposed to half-year, basis and since it was formed in 1998 it has delivered 10 successive annual increases in adjusted profit before tax. SSE is aiming to deliver a moderate, single digit increase in adjusted profit before tax in 2009/10 as a whole.

Adjusted profit before tax will, in practice and as always, be determined by issues such as: the availability of SSE's gas- and coal-fired power stations to generate electricity; the output of renewable energy from SSE's hydro electric stations and wind farms; the impact of the weather on actual level of energy consumption; and the interaction between wholesale prices for energy and the prices for electricity and gas charged to customers.

Adjusted Earnings Per Share*

To monitor financial performance over the medium term, SSE continues to focus on adjusted earnings per share* because it has the straightforward benefit of defining the amount of profit after tax that has been earned for each ordinary share and so reflects a clear view of underlying financial performance. In the six months to 30 September 2009, SSE's adjusted earnings per share were 34.2p, compared with 26.3p in the previous year.

DIVIDEND

Interim Dividend

SSE's first responsibility to shareholders is to deliver sustained real growth in the dividend. The Board is declaring an interim dividend of 21.0 pence per share, compared with 19.8p in the previous year. This is an increase of 6.1% compared with 2008/09 and is more than double the interim dividend paid in 2002, since when there has been compound annual growth in the dividend of 10.1%.

Future Dividend

According to the Capita Registrars Dividend Monitor, published in August 2009, dividend payments by UK companies fell by 9% in the first six months of 2009, compared with the same period in 2008, and are forecast to be 13% lower for the full year 2009.

Against this background, SSE remains acutely aware of its first responsibility to shareholders: to deliver sustained real growth in the dividend. Its target for 2009/10 as a whole is to grow the dividend by at least 4% more than inflation (based on the average rate of inflation in the UK between April 2009 and March 2010). The 6.1% increase in the interim dividend means the full-year dividend is likely to increase from 66.0 pence per share for 2008/09 to at least 70.0p for 2009/10.

Since 2005, SSE's target for dividends after 2010 has been 'sustained real growth', and that remains the case. It will, however, set out more defined dividend targets for 2010/11 and beyond by its full-year results statement in May 2010. After a period in which dividend payments by UK companies have come under severe pressure, or been abandoned altogether, SSE's priority in setting new dividend targets will be to ensure they are realistic and attainable, thereby giving shareholders the fullest possible confidence in their achievability.

SSE's strategy is explicitly designed to deliver sustained real dividend growth and its operational and investment decisions are all taken to support its achievement. Its long term goal remains the delivery of a full-year dividend double that paid in 2007 which, in turn, was more than double the first full-year dividend paid by SSE, in 1999.

INVESTMENT AND CAPITAL EXPENDITURE

Investment and Capex Key Performance Indicators Sep 09 Sep 08
£m £m
Thermal Generation 73.1 151.3
Renewable Generation 320.8 297.4
Electricity Networks 157.9 157.4
Gas Storage 29.7 22.9
Other 49.3 70.2
Total investment and capital expenditure 630.8 699.2
SSE share of SGN capital/replacement expenditure 104.7 79.9

Introduction

In March 2008, SSE set out plans to invest around £6.7 billion (excluding its share of Scotia Gas Network's spend) in the five years to March 2013 - one of the biggest capital investment programmes currently being undertaken in the UK by a FTSE 100 company.

The largest element of the investment programme is renewable energy, the requirement for which is underpinned by statute at EU and Member State level. At the same time, significant investment is also taking place in thermal generation, regulated electricity networks and in a number of other areas, such as gas storage.

In addition to the £6.7bn programme, SSE - through its 50% stake in Scotia Gas Networks (SGN) - is also making a significant investment in regulated gas networks. SSE's share of SGN's capital and replacement expenditure is currently forecast to total around £950m for the five years to March 2013.

All of this investment will support the maintenance and development of assets which are of strategic significance in the context of the energy trends identified in the EU Climate and Energy package, the UK Low Carbon Transition Plan, the Wicks report on energy security and Ofgem's analysis of the UK's energy supplies published in October 2009. It is, therefore, well-founded, in accordance with SSE's financial principles and it will deliver for SSE a significantly enhanced asset base and additional cash flows, which will support future dividend growth.

Investment in 2009/10

SSE is now 18 months into its five-year, £6.7bn programme of investment for the period to March 2013. In the six months to 30 September 2009, its capital and investment expenditure (excluding SGN) totalled £630.8m, compared with £699.2m in the previous year.

SGN's capital and replacement expenditure totalled £209.4m, compared with £159.8m in the previous year. SGN's capital investment of £90.4m takes the total for the 2008-13 Price Control period to £267.8m.

Over £1bn in total has been invested by SSE in assets which were still largely under construction at 30 September 2009, including its share of the developments at Marchwood (£172m), Greater Gabbard (£335m) and Aldbrough (£203m).

SSE's capital and investment expenditure of £630.8m compares with £288.0m in the same six-month period three years ago, in 2006. During that time, SSE (including Airtricity) has increased its onshore wind farm capacity by 550MW, managed the development at Marchwood of the UK's first new gas-fired power station for five years, completed the installation of flue gas desulphurisation equipment at Fiddler's Ferry and Ferrybridge power stations, developed the UK's first new gas storage capacity for four years and completed several major projects in electricity networks.

Nevertheless, a number of projects have encountered difficulties, such as the Glendoe hydro electric scheme, or have taken longer to complete than originally expected. SSE has examined them in detail in order to help ensure the successful delivery of current and future projects. From that, it is clear that the most successful projects are those which integrate rigorous engineering design, comprehensive risk management processes and a well-executed contracting strategy. The management of 'design and build' contractors is particularly important. SSE keeps the economic evaluation of its investment programme under continuous review and believes that value is being created on the basis of the most up-to-date project costs and schedules.

Major projects is an area in which SSE has now built up significant experience, which it is supplementing with the recruitment of additional expertise. The assets it is developing are intended to operate for decades, so SSE believes it is most important to implement best practice and invest sufficient time and resources during the development of the project, ensuring that robust assets are delivered, capable of generating revenue on a reliable basis over the long term. This approach is at the heart of SSE's management of major projects and will not be sacrificed in the interests of short-term concerns.

Future Investment Priorities in 2009/10 and Beyond

SSE now expects its capital and investment expenditure will be around £1.4bn for 2009/10 as a whole. In the two years to 31 March 2010, SSE will have undertaken capital and investment expenditure of around £2.7bn, which is 40% of the £6.7bn envisaged for the five years to March 2013.

The £6.7bn programme is constantly monitored and kept under review, to ensure that SSE is taking advantage of the best opportunities to invest and to make sure that the best projects are prioritised and take place at the optimum time. Increasingly, SSE will look beyond 2013 and a number of the opportunities for future investment in assets which it is currently expecting to develop from the middle of the next decade - such as offshore wind farms and nuclear power stations - will require investment decisions within the next few years.

The technology and construction risks involved in any individual investment decision are also very carefully considered, especially in the light of SSE's growing experience in major projects . All investment decisions are taken in a way which is consistent with SSE's financial principles, including maintenance of a strong balance sheet, and with securing returns which are greater than the cost of capital, enhance earnings and contribute to dividend growth.

FINANCIAL MANAGEMENT AND BALANCE SHEET

Key Performance Indicators Sep 09 Sep 08
Adjusted net debt (£bn) 4.95 4.65
Average debt maturity (years) 11.9 9.9
Underlying interest cover (excluding SGN) 3.7 3.6
Shares in issue (m) 922.1 874.3

Net Debt and Cash Flow

On an unadjusted basis, SSE's net debt was £5.037bn at 30 September 2009 compared with £5.100bn at 31 March 2009 and £4.689bn at September 2008. It expects that its unadjusted net debt at 31 March 2010 will be around £5.6bn.

There were outstanding liquid funds of £86.9m at 30 September 2009 relating to power purchase agreements and wholesale energy transactions. On an adjusted basis, therefore, including these liquid funds, SSE's net debt was £4.950bn at 30 September 2009, compared with £4.822bn at 31 March 2009 and £4.646bn at 30 September 2008. Adjusted net debt at 31 March 2010 is expected to be around £5.5bn.

Compared with the period to March 2009, during which there was substantial negative movement in working capital, the debt position at September 2009 has been supported by strong cash flow from operations and the positive unwinding of working capital.

Borrowings and Facilities

The objective for SSE is to maintain a balance between continuity of funding and flexibility, with debt maturities staggered across a broad range of dates. Its average debt maturity as at 30 September 2009 was 11.9 years, compared with 9.9 years as at 30 September 2008.

SSE's debt structure remains strong, with around £4.82bn of its adjusted net debt of £4.95bn in medium- to long-term borrowings in the form of issued bonds, European Investment Bank debt and long-term project finance and other loans. Within the £4.82bn total, £115m will mature in the period to 31 March 2011. The balance of SSE's adjusted net debt has been financed with short-term commercial paper and bank debt.

In September 2009, SSE issued a nine-year, £500m sterling bond, with a coupon of 5%. This took to around £2.9bn the total funding which SSE has secured since July 2008, from new bonds and loans with an average rate of interest of 6.17%; and an average maturity of around 12.3 years. Proceeds of £479m from the placing of 42 million new ordinary shares were also secured during that period, in January 2009.

Since the start of this financial year, SSE has entered into new committed bank facilities totalling £1bn, which mature in June 2012. This represents the refinancing and up-sizing of an existing £650m facility that had been due to mature in November 2009.

All of this demonstrates that SSE will move quickly to take the right financing options, including bonds, loans and, should new investment opportunities arise, equity.

SSE's investment programme is supported by its carefully-maintained balance sheet, which remains one of the strongest in the global utility sector. Its corporate credit ratings are now 'A-' (Standard & Poors) and 'A3' (Moody's). They were both downgraded earlier this year in line with the trend across the energy and utility sectors and with the revisions to their ratings criteria which the agencies chose to make, but they remain consistent with securing funding at a reasonable cost.

Net Finance Costs

The table below reconciles reported net finance costs to adjusted net finance costs, which SSE believes is a more meaningful measure. In line with this, SSE's adjusted net finance costs during the first half of 2009/10 were £168.4m, compared with £128.0m in the previous year.

Sep 09 Sep 08
£m £m
Reported net finance costs 196.0 13.5

add/(less)
Share of JCE*/Associate interest 45.8 63.5
Interest on convertible debt - (0.8)
Movement on derivatives (73.4) 51.8
Adjusted net finance costs 168.4 128.0
Return on pension scheme assets 49.7 68.4
Interest on pension scheme liabilities (63.8) (65.2)
Notional interest arising on discounted provisions (1.2) (0.8)
Adjusted interest costs** 153.1 130.4

The average interest rate for SSE, excluding JCE/Associate interest, during the period was 5.52%, compared with 5.51% for the previous year.

Based on adjusted interest costs, SSE's underlying interest cover for 2009/10 as a whole is currently expected to be around six times (excluding interest related to SGN), compared with 6.5 times in 2008/09; including interest related to SGN it is expected to be around 5.4 times. For the first six months (excluding interest related to SGN) it was 3.7 times, compared with 3.6 times in the six months to 30 September 2008.

Excluding shareholder loans, SGN's net debt at 30 September 2009 was £2.9bn, and within the adjusted net finance costs of £168.4m, the element relating to SGN's net finance costs was £24.8m (compared with £42.4m in the previous year), after netting loan stock interest payable to SSE. Its contribution to SSE's profit before tax* was, therefore, £74.7m, compared with £33.0m in the previous year.

Pensions

In line with the IAS 19 treatment of pension scheme assets, liabilities and costs, pension scheme liabilities of £579.1m are recognised in the balance sheet at 30 September 2009, gross of deferred tax. While scheme assets increased during the period, liabilities increased even more because of lower discount rates due to the tightening of spreads on corporate bonds. As a result, there was an increase in net liabilities of £305.6m compared with the position at 31 March 2009.

During the first six months of 2009/10, employer cash contributions amounted to:

As part of the Distribution Price Control for 2005-2010, it was agreed that allowances for 76% of deficit repair contributions in respect of the Southern Electric scheme should be included in price controlled revenue. In October 2009, Ofgem published a third consultation document on Price Control Pension Principles for the period 2010-15, which reaffirmed its ongoing commitment to full funding of all efficiently-incurred distribution business pension costs.

TAX

To assist the understanding of SSE's tax position, the adjusted current tax charge is calculated as follows:

Sep 09 Sep 08
£m £m
Reported tax charge 135.8 43.6

add back:
Share of JCE/Associate tax 14.1 8.2

less:
Deferred tax (22.4) (10.6)
Tax on certain remeasurements (33.1) 33.0
Adjusted current tax charge 94.4 74.2

The effective adjusted current tax rate, based on adjusted profit before tax*, was 23.0%, compared with 24.5% in the same period last year, on the same basis. The impact of SSE's higher capital expenditure programme and the changes introduced in Budget 2007 have had, and will continue to have, a positive impact on the effective current tax rate. The reduced rate has also been influenced by the accelerated plant and machinery capital allowances introduced in Budget 2009.

CONVERTIBLE BOND MATURITY AND AUTHORITY TO PURCHASE OWN SHARES

During the six months to 30 September 2009, SSE did not purchase any of its own shares for cancellation. SSE's 3.75% convertible bond, which had an initial nominal value of £300m, matured on 24 October 2009. The total number of shares in issue at 30 September 2009 was 922.1 million. The remaining 85,000 shares relating to the Convertible Bond were issued by 24 October 2009.

CORPORATE RESPONSIBILITY

Safety

SSE aims to create value for shareholders by maintaining a strong emphasis on its six core values, which include safety and sustainability. During the first six months of the year, SSE's Total Recordable Incident Rate (TRIR), which includes medical treatment, as well as lost-time and reportable injuries was 0.15 per 100,000 hours worked, the same as in the previous year. The number of lost time and reportable accidents within the company was 0.03 per 100,000 hours worked during the six months, compared with 0.05 in the same period in the previous year.

The number of serious, or potentially serious, blameworthy road traffic accidents involving employees driving company vehicles was 0.14 per 100 vehicles, compared with 0.13 in the previous year.

Environment

SSE's target for any given year is zero environmental incidents which result in it being served with a formal statutory notice by either the Environment Agency or the Scottish Environment Protection Agency. There were no such incidents during the first six months of 2009/10. SSE has, however, been charged under the Water Environment (Controlled Activities) (Scotland) Regulations 2005 and the Water Services (Scotland) Act 2003 following an escape of diesel from a holding tank at its Loch Carnan Power Station on Uist in November 2008.

Teamwork

On 30 September 2009, SSE employed 19,317 people, an increase of 522 in the six months since 31 March.

Risk Management

In its Annual Report 2009, SSE set out its approach to managing risk and six principal risk categories: strategic; market; credit; financial; operational; and regulatory and legislation. These remain the key risk categories for SSE and its approach to managing them remains in line with that set out in the Annual Report.

Company Name

SSE is currently listed as 'Scottish and Southern Energy plc', reflecting its geographical origins in the north of Scotland and the south of England. In the 11 years since it was formed, SSE's activities have extended throughout Great Britain and it also has significant operations in Northern Ireland and the Republic of Ireland. It is also beginning to develop assets in mainland Europe, and its full name is beginning to prove unwieldy. As a result, it will seek approval from shareholders at its Annual General Meeting in July 2010 to change the name under which it is listed to that by which it is most commonly known, SSE, to become 'SSE plc'.

FURTHER INFORMATION

Disclaimer

This financial report contains forward-looking statements about financial and operational matters. Because they relate to future events and are subject to future circumstances, these forward-looking statements are subject to risks, uncertainties and other factors. As a result, actual financial results, operational performance and other future developments could differ materially from those envisaged by the forward-looking statements.

Investor timetable

Ex-dividend date 17 February 2010
Record date 19 February 2010
Payment date 26 March 2010

Financial results for 2009/10 20 May 2010
AGM (Bournemouth) 22 July 2010

Enquiries

Scottish and Southern Energy plc
Alan Young (Director of Corporate Affairs) UK 0845 0760 530

Sally Fairbairn (Investor Relations Manager)

Financial Dynamics
Andrew Dowler +44 (0)20 7831 3113

Analysts' presentation

Start: 0900 (GMT)

Location: Financial Dynamics, Holborn Gate, 26 Southampton Buildings, London WC2A 1PB

Webcast facility

You can join the webcast by visiting www.scottish-southern.co.uk, then clicking on Investor Centre.

Conference call

International +44 (0) 1452 542 303

Online information

News releases and announcements are made available on SSE's website at www.scottish-southern.co.uk. You can also follow the latest news from SSE through Twitter at www.twitter.com/sseplc

Generation and Supply Overview

SSE owns around 11,100MW (megawatts) of capacity for generating electricity, an increase of almost 400MW since 1 April 2009. Its 420MW share of the capacity of the UK's first new gas-fired power station for five years at Marchwood, near Southampton, which should become operational shortly, will take the total to over 11,500MW.

The large majority (over 10,700MW) of this capacity is in Great Britain, with the remainder (400MW) in Northern Ireland and the Republic of Ireland, where there is an all-island Single Electricity Market which is separate from the market in Great Britain.

SSE's total capacity includes its share of joint ventures and associates and comprises around:

This balance between coal- and gas-fired generation capacity, and the balance between fossil fuel and renewable sources of energy, gives SSE the greatest diversity in fuels for generating electricity among UK generators and avoids dependency on a single technology or commodity. As a result, SSE has significant optionality in the management of its power stations. It is this diversity and the optionality that goes with it which enable SSE to manage the risks inevitably associated with primary fuel procurement.

As at 30 September 2009, SSE supplied energy to 9.15 million customer accounts in Great Britain and 100,000 accounts in Northern Ireland and the Republic of Ireland, making it the second largest supplier within Great Britain's competitive electricity and gas supply market and the fourth largest supplier in the Irish all-island market.

SSE's Trading and Risk Management team is responsible for its participation in wholesale markets for electricity and gas, as well as markets for coal, oil and carbon dioxide emissions allowances. Through analysis of generation plant availability, customer demand and its contractual position SSE can assess, and therefore manage, its exposure to market prices. In terms of the forthcoming winter, SSE believes it has in place appropriate operational and commercial arrangements to manage its energy supply commitments in all likely circumstances.

In summary, SSE manages Generation and Supply as a single value chain within an integrated business. Its power stations and fuel supply contracts are used to support performance in electricity (and, by extension, energy) supply. For this reason, SSE seeks to maintain a well-balanced portfolio of assets, contracts and customers, and over the past seven years its growth in power station capacity has been similar to its growth in customer numbers. This integrated business, featuring a diverse range of assets has, therefore, value that goes beyond the sum of its parts - not least because its exposure to particular commodity price outcomes is reduced.

Generation and Supply Performance

Operating profit* in Generation and Supply was £227.4m compared with £107.7m in 2008 and £474.3m in 2007, contributing 39.3% of SSE's total operating profit* in the first half of the year. The reasons for this are set out under 'Adjusted Profit Before Tax for the Six Months to 30 September 2009', above. (SSE reports the underlying financial performance of Generation and Supply excluding the impact of IAS 39 remeasurements which are unrealised as including them does not represent underlying business performance.)

Total revenue for Generation and Supply for the six months to 30 September 2009 was £7.5bn, which accounted for 89% of SSE's total revenue, of which £3.5bn was in relation to sales of electricity and gas to industrial, commercial and domestic customers.

During the first half of the year (within the Great Britain), SSE generated 17.1TWh of electricity at thermal power stations in which it has an ownership or contractual interest, compared with 16.5TWh in the previous year. It generated 2.0TWh from renewable sources of energy, including pumped storage. It also purchased 2.7TWh of electricity through long-term contracts with other generators. It supplied 28.1TWh of electricity to its industrial, commercial, small business and domestic customers. Any net balances were traded in the wholesale electricity market.

While around 55% of annual electricity consumption and around 75% of annual gas consumption occurs in the six months to 31 March, it already seems likely that customers' demand for electricity - and gas - in the UK will be lower in 2009/10 than it was in the previous year as a result of both the impact of investment in energy efficiency and the downturn in the economy. In this context, SSE's long-standing approach of actively maintaining balance in its portfolio of assets, contracts and customers remains of particular relevance and means it is not over-exposed to variations in demand for energy.

Consolidated Segmental Statement

Ofgem has introduced a new requirement on electricity generators and suppliers to publish a Consolidated Segmental Statement showing revenue, costs and profits from electricity generation and electricity and gas supply activities. This statement must be published no later than six months after the end of the current financial year (ie by 30 September 2010). The requirement to produce such a statement will not have any significant impact on the presentation of Generation and Supply in SSE's financial statements and will not undermine SSE's long-standing approach of managing its Generation and Supply activities as a single value chain.

GENERATION

Electricity Generation Key Performance Indicators Sept 09 Sept 08

ASSETS (MEGAWATTS - MW)*
Gas- and oil-fired generation capacity 4,500 4,500
Coal-fired generation capacity (inc biomass co-firing) 4,360 4,000
Renewable (inc pumped storage) generation capacity 2,250 2,000
Total electricity generation capacity (MW) 11,110 10,500

OPERATIONS (%)
Gas power station availability 89 70
Coal power station availability 94 92
Hydro storage 54 33
Wind farm availability 97 97

OUTPUT (TWh/GWh)*
Gas- and oil-fired - TWh 13.9 14.3
Coal-fired (inc biomass co-firing) - TWh 3.2 2.2
Total output from thermal power stations - TWh 17.1 16.5

Conventional hydro - GWh 1,380 1,064

Context

Over the next decade, around 20GW of the UK's capacity for generating electricity (largely coal, oil and nuclear) is scheduled to close because of its age or its inability to comply with higher environmental standards. In July 2009, the UK government's UK Low Carbon Transition Plan included a projection of possible shares of electricity generated from different sources in 2020, based on energy demand estimated at 370TWh:

All of this has five major implications for electricity generation:

In this context, SSE's key objectives in Generation remain relevant and appropriate. They are to:

In achieving these objectives, SSE's target is to reduce by 50% the carbon dioxide intensity of electricity produced at power stations in which it has an ownership or contractual interest, over the period from 2005/06, the first full year after it acquired coal-fired power stations, to 2020.

Gas-fired Generation - Operations

Good performance in Generation and Supply is dependent, first and foremost, on plant at power stations being available to generate electricity as and when required. SSE owns 4,500MW of gas- and oil-fired electricity generation capacity, including its share of joint ventures.

During the six months to 30 September 2009, SSE's principal wholly-owned gas-fired power stations (Fife, Keadby, Medway and Peterhead) achieved 89% of their maximum availability to generate electricity, excluding planned outages, compared with 70% availability in the same period in 2008. This reflected the return to service in June of Medway power station, following a 15-month unplanned outage. Excluding Medway, the availability of SSE's wholly-owned gas-fired power stations was 96%.

SSE's Engineering Centre has completed a detailed review of the way that its power-producing assets are managed, supported by external engineering advisers. It has confirmed that the management of SSE's power station plant, and the decision-making that is part of that, is good. At the same time, it has identified potential improvements in the execution of maintenance.

Against this background, SSE has designed an updated model for managing its generation assets with four key stages:

The adoption of a consistent approach in the management of its assets, which have different characteristics and which have been developed, acquired or upgraded over a number of years, plus other steps such as the acquisition of strategically-significant spare parts for generating plant to mitigate major failures and the ongoing development of the Engineering Centre itself, including its Equipment Performance Centre, should help SSE ensure its generation assets deliver on a consistent basis good levels of availability to generate electricity.

The forthcoming increase in electricity generation from renewable sources, which means gas-fired and coal-fired power stations will have to be increasingly flexible and run at lower load factors than has historically been the case, will present additional engineering challenges which, although far from insuperable, will require optimum asset management in the future.

Gas-fired Generation - Investment

Ofgem's Project Discovery - Energy Market Scenarios, published in October 2009, highlighted that Britain will face significant levels of gas imports, in particular for gas-fired power plants to replace lost nuclear and coal-fired capacity, and that this will increase the country's exposure to uncertainties in the global gas market. That is why it would not make sense to run the risk of becoming over-dependent on a single fuel. Nevertheless, CCGT continues to be the benchmark technology in generation, making a growing contribution to meeting the UK's electricity requirements, because of its high thermal efficiency, relatively low costs and short construction time.

The 840MW CCGT (combined cycle gas turbine) plant in Southampton being developed by Marchwood Power Ltd, a 50:50 joint venture between SSE and ESB International, is undergoing reliability testing and the plant should be in full commercial operation shortly. With a net thermal efficiency in excess of 58%, it is one of the most efficient gas-fired power stations in the UK. SSE's total investment in Marchwood will be around £200m (comprising equity and debt). All of the station's output is contracted to SSE. The plant was procured before the significant increase in costs experienced in the electricity generation sector in 2007 and 2008, making it a particularly well-timed and well-founded investment.

In May 2009, SSE entered into an agreement to acquire Abernedd Power Company Limited from BP Alternative Energy. Abernedd has applied to the Secretary of State for Energy and Climate Change for consent to construct and operate a new CCGT power station, with a capacity of over 800MW, on a brownfield site in Baglan Bay in south Wales, where there is already in place electricity transmission, gas and water infrastructure for the first phase of the power station. The total cash consideration will be determined by the progress of the development, and SSE hopes that planning consent to build Abernedd will be secured during the course of 2010.

In line with that, and subject to timely planning consent being secured, SSE expects to construct the new power station in two phases to maximise plant flexibility. In the first phase, a unit with capacity of over 400MW will be developed, with a view to becoming operational around 2013 or 2014; a second unit, with a similar capacity, could become operational around 2016 or 2017. The two-unit approach gives SSE greater flexibility in the timing and nature of the development and a final investment decision on the first phase will be taken later next year.

In addition, SSE has identified other options for additional CCGT capacity. These include:

Coal and Biomass Generation - Operations

During the six months to 30 September 2009, SSE generated 3.2TWh of electricity at its coal-fired power stations at Fiddler's Ferry and Ferrybridge, compared with 2.2TWh in same period in the previous year. The stations achieved 94% of their maximum availability to generate electricity, excluding planned outages, compared with 92% in the previous year.

The increase in output reflects the removal, in the early part of 2009, of the constraints on running hours at the stations imposed by Article 5(1) of the Large Combustion Plant Directive (LCPD), following the hot commissioning of flue gas desulphurisation (FGD) equipment.

The installation of FGD equipment means that the power stations are able to use higher-sulphur coal mined in the UK. As a result, in April 2009, SSE entered into an agreement with UK Coal, under which it will obtain 3.5 million tonnes of deep- and surface-mined coal from Great Britain, including Kellingley Colliery in West Yorkshire, to provide fuel for Ferrybridge power station up to 2015. This should be enough to meet around 15% of the station's requirements during that period. In addition, SSE has advanced a secured loan to UK Coal, on which it will receive interest, to be repaid by 2014.

The stations 'co-fire' fuels from renewable sources (biomass) in order to displace fossil fuels. During the period, their output qualifying for ROCs (Renewable Obligation Certificates - see below) was 0.1TWh, similar to the same period in the previous year (included within the above total for the stations as a whole). From 1 April 2009, electricity output resulting from co-firing receives 0.5 ROCs per MWh (compared with 1.0 ROC per MWh previously) and electricity suppliers can only meet up to 10% of their Renewables Obligation from this technology.

In August 2009, SSE acquired Uskmouth Power Company Limited, the owner and operator of the 363MW Uskmouth coal-fired power station near Newport, South Wales for a total cash consideration of £27m (including cash and working capital balances).

Uskmouth comprises three independent power generating units, each with 121MW of capacity. The power station dates from the 1960s and was substantially refurbished in 2000, including having FGD equipment fitted. It routinely operates on a two-shift basis to help meet shorter-term power requirements.

Following the acquisition, around 100 people employed at the station joined SSE. The integration of Uskmouth into SSE's portfolio of power generating assets has gone well and the station is in a good position to help meet peak demand for electricity during the coming winter.

Coal and Biomass Generation - Investment

The LCPD also requires reduced emissions of nitrogen oxides, and SSE has already invested £31m to install SOFA (Separated Overfire Air) and BOFA (Boosted Overfire Air) equipment at the stations. From 2016 limits on those emissions from power stations will be tightened significantly. As a result, SSE is undertaking a front-end engineering design (FEED) study, which it expects to complete next year, into options for installing Selective Catalytic Reduction (SCR) technology at Fiddler's Ferry and is also considering the option for Ferrybridge. The alternative to fitting SCR is to operate the station within limits required under a derogation from the LCPD's requirements. SSE's analysis of the issues around installing SCR will also take into consideration the progress of the draft EU Industrial Emissions Directive which the European Commission has proposed in order to overhaul seven existing pieces of legislation on industrial emissions, including the LCPD, into a single directive.

Coal and Biomass Generation - Carbon Capture and Storage

Although its carbon intensity is a critical factor, coal is a vitally important fuel for the UK, because of its flexibility, its availability and because it reduces the reliance on imported gas highlighted most recently in Ofgem's Project Discovery report.

In April 2009, the UK government confirmed all new combustion power stations over 300MW in England and Wales would have to be designed 'carbon capture ready' so that they could fit Carbon Capture and Storage (CCS) technology. It has also completed a consultation on a series of proposals to advance the development of clean coal, including requiring new coal power stations to demonstrate CCS on a defined parts of its capacity and to retrofit CCS to their full capacity within five years of CCS being independently judged technically and commercially proven.

SSE is continuing to examine a range of options for development at Ferrybridge, following the expected closure in 2015 of that plant at the station (1,000MW) which is not opted in to the LCPD. This will leave the station with significant assets in terms of land, a connection to the electricity grid, cooling water and a railhead. (See 'Biomass' section below.)

It has submitted a planning application for consent to trial carbon dioxide capture technology at Ferrybridge power station, in collaboration with Doosan Babcock. The companies are investing a total of £21m, including funding being sought from public agencies. Construction work is expected to start next year, with the trial itself expected to commence in early 2011 and be complete by the end of 2012.

The scale of the project, with the equivalent 5MW of coal-fired power generating capacity producing 100 tonnes of carbon dioxide per day, bridges the gap between the various laboratory-scale trials that are under way and the larger-scale projects envisaged by the UK government. The significance of the project lies in its scale, and its ability to demonstrate the operational characteristics of capture plant on an actual power station and the performance of the amine compound on real flue gas.

Development of viable CCS technology is central to the UK's climate change and energy security objectives and SSE believes demonstration projects such as this and other CCS initiatives in which it is involved will be crucial in establishing when and how the technology can be developed. It is crucial that it should be. SSE believes that, in practice, no new coal-fired power generation plant should be built in the UK without carbon dioxide abatement and that no unabated coal-fired plant should remain operational much beyond 2030.

Coal and Biomass Generation - Sustainability

The development by Lafarge Plasterboard Ltd of a plasterboard factory at Ferrybridge has been completed. The plant is operational and using the gypsum produced on site as a result of FGD in the production of plasterboard.

The development by RockTron (Widnes) Ltd of an ash separation plant at Fiddler's Ferry is now complete and moving into operation. It removes and processes all fresh ash produced by the power station, and much of that currently stored in lagoons at the site, turning it into constituent parts which become marketable products for use in products such as cement, water filters, car components and ultra-lightweight paint for aircraft.

SSE now has 49.9% of the equity in RockTron (Widnes) Ltd, a subsidiary of RockTron Ltd, enabling it to secure a share of the income from the ash separation plant, in addition to the benefits which will result from avoiding the environmental liabilities associated with ash production and storage.

EU Emissions Trading Scheme

Phase II of the EU Emissions Trading Scheme (EU ETS) began on 1 January 2008. Across its electricity generation portfolio (taking account of contractual shares), SSE now has an allocation of almost 17 million tonnes of carbon dioxide emissions allowances per annum. In addition, Marchwood Power Ltd has an allocation of almost five million tonnes reserved to it from when it is commissioned to the end of Phase II. In the six months to 30 September 2009, the price of allowances ranged from around EUR12 to EUR16 per tonne; the market itself is still relatively new and has yet to mature fully. From 2013, all of the carbon dioxide emissions allowances for electricity producers will be auctioned.

Renewable Energy - Overview

Tackling climate change and securing future supplies remain the two goals of energy policy in the UK, Ireland and the EU. Against this background, the EU Renewable Energy Directive imposes legally-binding targets on EU Member States, specifying the proportion of all energy consumption that must be met by renewable energy sources by 2020. The national target for the UK is 15% (compared with under 2% in 2007) and for the Republic of Ireland it is 16%. The UK government envisages that over 30% of the country's electricity requirements will have to be met from renewable sources by 2020, and an even greater proportion is likely to be required in the Republic of Ireland.

The Energy Act 2008 enabled the introduction of 'banding' of the Renewables Obligation (RO) to allow differentiated levels of support for different renewable energy technologies. From 1 April 2009, electricity from qualifying hydro electric schemes and onshore wind farms continues to receive one ROC per MWh; from offshore wind farms it is now 1.5 ROCs per MWh.

In July 2009, the UK government published the UK Renewable Energy Strategy and a Consultation on Renewable Electricity Financial Incentives 'to provide the right financial framework to harness the ingenuity and the innovation of individuals, communities and companies to drive renewables and make them tomorrow's mainstream energy choices'.

SSE believes proposals to strengthen the Renewables Obligation, by extending its lifetime and 'headroom' (in other words, the gap between the level of the Obligation and the amount of ROCs actually produced, thereby maintaining their value), should be welcomed. The proposal to increase ROCs from 1.5 per MWh to 2.0 for offshore wind projects meeting specified completion criteria if they place new orders in 2009-10, and then 1.75 in 2010-11, is clearly discriminatory and SSE, along with several other major offshore wind farm developers, is continuing to engage with the UK government to find a way to deliver appropriate support levels but in a non-discriminatory manner.

In the Republic of Ireland, the Renewable Energy Feed In Tariff (REFIT) scheme is used to support renewable energy by providing a guaranteed price for output and a 15% rebate (subject to a cap) on suppliers' purchase of REFIT energy.

SSE has 2,250MW of commissioned renewable energy capacity in the UK and Ireland, comprising hydro electric schemes (including pumped storage), wind farms and a dedicated biomass facility at Slough, an increase of 30MW since the start of the financial year. Of this, almost 1,000MW qualifies for ROCs (including dedicated biomass). Total output from all of SSE's conventional hydro electric schemes, wind farms and its dedicated biomass plant was 2,360GWh in the six months to September 2009, compared with 1,803GWh in the same period in 2008 and 1,314GWh in 2007.

Looking ahead, it has set itself the target of owning and operating 4,000MW of renewable energy capacity in the UK and Ireland by the end of 2013. The achievement of this milestone will mean SSE is making a significant contribution to the achievement of the 2020 targets in the UK and Ireland, and it has extensive opportunities to build on its 2008-13 programme of investment in renewable energy in the subsequent years. This investment is being, and will continue to be, supported by firmly-established financial frameworks such as the Renewables Obligation to ensure there is an adequate incentive for energy companies to make the financial commitment involved in developing renewable energy to help meet EU Member States' legally-binding targets.

Moreover, in addition to the clear environmental benefits associated with harnessing their power, water and wind are key sources of free and indigenous primary energy which reduces SSE's exposure to volatile prices for fossil fuels, sources of which are in decline but which will be in huge demand from growing, populous economies around the world.

In addition to its focus on the UK and Ireland, SSE is undertaking in the same period a programme of development in renewable energy in new markets in continental Europe (principally Portugal, Scandinavia, Italy, Germany and the Netherlands).

Hydro Generation - Operations

SSE owns and operates just over 1,450MW of capacity in conventional hydro electric schemes, including the 300MW pumped storage facility at Foyers.

Total output from the conventional hydro electric schemes was 1,380GWh during the six months to 30 September 2009, compared with 1,064GWh during the previous year. As at 30 September 2009, the amount of water held in SSE's reservoirs which could be used to generate electricity was 54% of the maximum, compared with 33% in the previous year. Output from Foyers was 175GWh, compared with 58GWh in the previous year.

In order to encourage long-term investment to maintain smaller schemes, the output of refurbished hydro electric stations with capacity of up to 20MW qualifies for ROCs. SSE has just over 400MW of capacity in this category (including the new plant commissioned in the last few years at Culleig, Kingairloch and Fasnakyle). In addition, the output from all new hydro electric schemes also qualifies for ROCs. Of SSE's total hydro output, 708GWh qualified for ROCs, compared with 543GWh in the previous year.

In August 2009, SSE identified a blockage caused by a fall of rock near the top of the tunnel carrying water from the reservoir to the power station at the 100MW Glendoe hydro electric scheme. Investigations have confirmed that the amount of debris is very substantial, but confined to a section near the top. SSE is now examining options in order to identify the best way to achieve a resumption of electricity generation at the site, including possible construction of a tunnel to by-pass the blockage, all of which will require a significant programme of work.

SSE now believes that the extent of the repairs required means it is very unlikely that any electricity will be generated at Glendoe until the financial year 2011/12. It also believes that a significant proportion of the financial consequences of the situation at Glendoe will be covered by contractual arrangements and insurance provision.

Hydro Generation - Investment

Since the Renewables Obligation was introduced in April 2002, SSE has invested almost £310m in refurbishing and developing conventional hydro electric schemes in Scotland, including Glendoe. The programme of investment to prolong their working life and improve their operational efficiency totalled £7m in the first half of 2009/10.

Hydro electric schemes which use impounded water to generate electricity have an important part to play in meeting peak demand and also complement the growing, but variable, amount of output from wind farms. Against this background, SSE has submitted to Scottish Ministers an application for consent to develop a 60MW pumped storage scheme as part of its 152MW Sloy power station, near Loch Lomond. This means that in addition to electricity produced from water collected and held in the Loch Sloy reservoir, Sloy would generate electricity using water pumped from Loch Lomond to the reservoir.

In an average year, Sloy produces around 120GWh of electricity and adding to it to a pumped storage facility would allow it to produce an additional 100GWh of electricity in a typical year to help meet peak demand. SSE currently expects that developing a pumped storage facility at Sloy will require investment of over £30m.

In addition, SSE is proposing to develop two new large scale pumped storage hydro electric schemes at Coire glas at Loch Lochy and Balmacaan at Loch Ness . In October 2009, it asked the Scottish Government for its formal opinion on the scope of the environmental impact statement that would accompany planning applications for the schemes, currently planned to be submitted during 2011. Construction is unlikely to start before 2013 at the earliest.

They would be the first brand new pumped storage schemes to be developed in Great Britain since work began on the Dinorwig scheme in Wales in 1974. Subject to final agreements and design, it is envisaged that the proposed schemes would have an installed capacity of between 300MW and 600MW each and each would be able to produce in excess of 1,000GWh of electricity in a typical year to help meet peak demand. In both cases, the upper reservoirs would be large, enabling electricity generation to continue for longer periods, without the need to pump water from the loch below, than is the case for other pumped storage schemes in Great Britain.

Both schemes would require the construction of a dam in order to impound water and create the upper reservoirs, but it is currently envisaged that water pumping and electricity generation at both developments will be carried out under ground, thereby avoiding any visual impact in the Great Glen itself.

Wind Generation - Operations

As at 30 September 2009, SSE owns and operates 720MW of onshore wind farm capacity in the UK and Ireland, compared with 690MW at 31 March 2009. Of the 30 September total, 325MW is in the Republic of Ireland. It also has 2MW of onshore wind farm capacity in Portugal.

Total output from SSE's portfolio of wind farms in the UK was 463GWh during the six months, all of which was eligible for ROCs, compared with 341GWh in the previous year; from its wind farms in the Republic of Ireland, the output was 393GWh, compared with 297GWh in the same period in 2008. On average, the turbines at SSE's wind farms in the UK and Ireland achieved 97% of their maximum availability to generate electricity.

Wind Generation - Investment Overview

When SSE entered into the agreement to acquire Airtricity (the renewable energy development division which has since been re-named SSE Renewables), in January 2008, the combined business had just over 870MW of onshore wind farm capacity in operation, in construction or with consent for development in the UK and Ireland. This has now doubled and currently totals 1,750MW, comprising (net):

In addition, SSE has submitted for approval by the relevant planning authorities in the UK and Ireland proposals for onshore wind farms with a total capacity of over 950MW. This includes SSE's share of the capacity contained in the proposal by Viking Energy, a 50:50 joint venture between Viking Energy Ltd (which is 90% owned by Shetland Charitable Trust) and SSE to develop on Shetland's Central Mainland a wind farm with 540MW of capacity. Beyond this, SSE has over 1.5GW of onshore wind farm capacity development opportunities in the pre-planning phase in the UK and Ireland and over 3GW under development in mainland Europe.

SSE also has a 50% share of the 500MW Greater Gabbard wind farm now under construction in the outer Thames Estuary (see below). This means that SSE now has: 3,530MW of renewable energy capacity (onshore wind, offshore wind, hydro and dedicated biomass) in operation, under construction or with consent in the UK and the Republic of Ireland. It also has over 1,900MW of offshore wind farm capacity with consent for development in northern Europe, including the Dutch sector of the North Sea.

The principal projects within SSE's five year programme are the Clyde and Griffin onshore wind farms and the Greater Gabbard offshore wind farm.

Wind Generation Investment - Clyde

Clyde has consent for 152 turbines and the total planned capacity at the wind farm is 350MW. In September 2009, a contract was placed with Siemens for the provision of the turbines. Work at the site is now getting under way. Following agreement on a primary radar mitigation scheme in July, discussions are progressing on the secondary radar issues. Clyde is expected to have a load factor of around 35% and produce over 1,000GWh of electricity in a typical year. Its construction cost is expected to be around £500m. First commissioning is scheduled for 2011 and completion of both phases is scheduled for 2012.

Wind Generation Investment - Griffin

Pre-construction work is also under way at the Griffin wind farm in Perthshire, in which SSE acquired its interest in the early part of 2009, in advance of full construction work beginning before the end of this financial year. A tendering process for turbines for the site is under way. The final capacity and output will depend on the final turbines selected, but the capacity will exceed 120MW. Its construction cost is dependent on the final turbine selection but is expected to be up to £200m and the project should be completed in 2012.

Wind Generation Investment - Greater Gabbard

Greater Gabbard Offshore Winds Limited ("GGOWL") is a 50:50 joint venture between SSE and RWE npower renewables, to develop in the outer Thames Estuary what is the world's largest offshore wind farm under construction.

Offshore construction work is continuing with the installation of the first 30 of the 140 turbine foundation monopiles and the first of two offshore transformer platforms now completed. Prior to installation of the foundations a number of potential quality issues were identified in the welds of the first three of eight production batches, which had some impact on the start of the installation programme. GGOWL's contractor is satisfied that the issues identified with the foundation monopiles do not affect the dates for the first electricity generation and completion, which remain at 2010 and 2012 respectively.

GGOWL employs Fluor Corporation to complete the procurement, engineering and construction of the development and is confident it will achieve an entirely satisfactory outcome to any claim for additional costs that Fluor may choose to make as a result of the issues arising from the first batches of foundations, and that any claim should be resolved as part of the normal contractual process.

Based on site-specific met mast data collected since 2005, Greater Gabbard is expected to have a load factor of over 40% and produce around 1,900GWh of electricity in a typical year, of which SSE will take 50%. Its operations and maintenance will be carried out by SSE Generation, under a management services agreement with GGOWL. The wind farm is expected to require a total investment by SSE of around £650m, excluding connection to the electricity grid.

With SSE's contractors remaining confident that there will be sufficient progress during the coming months to ensure the project remains on course to produce electricity for the first time in 2010 and to be completed in 2012, the long-term value of the project is unaffected by the slower-than-expected start to offshore work.

Wind Generation Investment - Other Offshore Wind in the UK

SSE expects that Greater Gabbard will prove to be the first of a series of major offshore wind farms which it develops over the next decade. Its other potential opportunities include:

Partnerships with other developers such as this are intended by SSE to minimise risks involved in offshore wind projects and to maximise the development capability.

Wind Generation - Businesses and Communities

Energy price certainty and environmental targets continue to drive businesses' demand for wind turbines sited on their premises and there is significant community interest in the potential for wind energy to help meet sustainable energy needs and bring local benefits. SSE's first consented community wind turbine will be erected in 2010 for the Sanday Development Trust on the Orkney island of Sanday. A further 50MW of projects are nearing readiness for submission to the relevant planning authorities and 450MW of projects are currently in development.

Wind Generation Investment - Onshore in Europe

In addition to its wind and hydro investments in the UK and Ireland, SSE has options to invest in renewable energy in Europe, principally Portugal, Scandinavia, Italy, Germany and the Netherlands where there are particular opportunities for growth in renewables. Any investment will involve working with partners and will largely be on an equity basis, with non-recourse or project-specific debt typically expected to account for around 75% of the total cost of the investment.

SSE's principal onshore wind ventures in mainland Europe are now:

The acquisition of Airtricity (since re-named SSE Renewables) extended the scope of SSE's interests to continental Europe, thereby giving it development and operational activity in a new geographical location. SSE continues to believe that the scope for the development of its existing businesses in the UK and Ireland is very substantial, and investments in the UK and Ireland will continue to be prioritised. Any activity in Europe will be limited, disciplined and generally undertaken in conjunction with local joint venture partners.

Marine Energy

SSE now has a 47% stake in Aquamarine Power, which in September 2009 successfully completed the first round of its fundraising to raise £10m from investors in the UK and Ireland. This followed the successful deployment of a full scale demonstrator of Aquamarine's 300KW (kilowatt) Oyster wave energy converter at its testing berth at the European Marine Energy Centre (EMEC) in Orkney. Testing is expected to take up to two years. Aquamarine expects to have a fully commissioned, commercially available wave farm in place by 2014. It also has an agreement with SSE to develop sites in the UK and the Republic of Ireland capable of hosting up to 1,000MW of marine energy capacity by 2020 using Oyster technology. SSE is also working with a number of other technology providers to exploit potential marine energy resources around the UK and Ireland.

Biomass and Multi-fuel - Operations

SSE's plant at Slough has a current generating capacity of 80MW and remains the UK's largest dedicated biomass energy facility. During the six months to 30 September 2009, it produced 124GWh of electricity qualifying for ROCs, up from 101GWh in the same period in the previous year. The output from dedicated regular biomass plants attracts 1.5 Renewables Obligation Certificates (ROCs) per MWh.

Biomass and Multi-fuel - Investment

Experience of managing the plant at Slough gives SSE a platform from which to invest in biomass and waste-to-energy. In line with its approach to developing a number of options for the site, SSE has submitted an application for consent to develop for a multi-fuel combined heat and power (CHP) facility at Ferrybridge. The proposed multi-fuel CHP facility will use a range of fuel sources, which could include biomass, waste-derived fuels and wood products, to generate around 90MW of electricity and to provide heat to the Ferrybridge site. It will be compliant with the Waste Incineration Directive. In addition, the acquisition of Uskmouth power station gives SSE further opportunities to develop new lower carbon generation assets alongside the existing generation assets.

Biomass and Multi-fuel - Forth Energy

Forth Energy, the joint venture between SSE and Forth Ports PLC created in 2008, has prepared proposals for the development of dedicated biomass power stations at four of Forth Ports' sites in Scotland. It will undertake consultations on the proposals and intends to seek consent next year to build the plants. The plants are proposed for Dundee, Leith, Rosyth and Grangemouth. Their total installed capacity would be around 400MW and they could also produce heat to be used at other facilities at the Forth Ports' sites and, potentially, other neighbouring sites.

Emerging Technologies - SSE Ventures

In February 2007, SSE set up SSE Ventures (SSEV) to develop and grow its portfolio of investments in small and medium-sized businesses offering renewable, sustainable and energy efficiency-enhancing products and services. These include Aquamarine Power and RockTron (Widnes) Ltd (see above). In addition to the financial support offered, SSEV works in close partnership with investee companies to help their products or services make progress towards full commercial viability.

Participation in emerging technology developments helps SSE to anticipate, be at the forefront of, and adapt to, the kind of changes in energy production and consumption that are likely to occur over the next decade. In the six months to 30 September 2009, through equity and loans, SSEV committed to investing just under £10m in a variety of emerging technologies, taking the total to almost £100m. It now holds direct or indirect stakes in a total of 30 companies.

Nuclear Power

It is expected that the total capacity of the UK's nuclear power stations will fall by over 7,000MW by 2020 (even if advanced gas - cooled reactor (AGR) stations are allowed by the Nuclear Installations Inspectorate to operate for five years beyond their existing planned closure dates). History suggests that the performance and reliability of nuclear power stations with extended lives tends to deteriorate markedly.

These question marks do not apply to modern nuclear power stations, which Malcolm Wicks MP said in his August 2009 report represent a proven, low carbon generation technology which could benefit security of energy supply by increasing the diversity of the fuel mix and reducing reliance on gas imports. He suggested that nuclear power should provide some 35%-40% of the country's electricity after 2030.

A consortium of GDF Suez SA, Iberdrola SA and SSE has been successful in securing an option to purchase land for the development of new nuclear power generating plant adjacent to Sellafield in Cumbria, from the Nuclear Decommissioning Authority for a total cash consideration that could reach £70m.

The consortium now intends to prepare detailed plans for developing new nuclear power generating plant at the site with a total capacity of up to 3.6GW. These plans will be prepared in consultation with the safety authorities and local stakeholders and will be submitted for consideration by the relevant planning authorities, with the aim of being able to begin construction of the first new reactor around 2014.

ENERGY SUPPLY

Energy Supply Key Performance Indicators Sept 09 Sept 08
Electricity customer accounts (GB domestic) - m 5.18 5.12
Gas customer accounts (GB domestic) - m 3.54 3.37
Energy customers (GB business sites) - m 0.43 0.41
Total GB energy customer accounts - m 9.15 8.90
All-Island Energy Market customers (Ireland) 100,000 40,000
Home services customer accounts (GB) 372,000 283,000
Total customer accounts (GB and Ireland) - m 9.625 9.220
Electricity supplied - GWh (GB) 28,104 27,517
Gas supplied - m therms (GB) 486.6 560.1
Complaints/referrals to Energy Supply Ombudsman and Consumer 478 726

Direct(GB)

Context

In September 2009, the UK's Department of Energy and Climate Change stated that: 'Estimates suggest that, for the period July to December 2008, prices for medium domestic gas and electricity consumers, including tax, were the lowest and seventh lowest in the EU 15 respectively.'

Nevertheless, energy supply remains a high profile issue and, in August 2009, the Chief Executive of Ofgem wrote to energy suppliers to urge them to 'explain how cost changes, including falling wholesale costs, are likely to bear on future energy bills'. In response, SSE said higher forward annual wholesale prices and higher distribution, environment and social costs all counter falls in wholesale prices.

Before that, in July 2009, the UK government's UK Low Carbon Transition Plan set out a series of measures to reduce significantly the amount of energy consumed by customers, including extending the Carbon Emissions Reduction Target (CERT) to 2012, mandating the installation in all homes of smart meters by 2020 and undertaking the 'Great British Refurb' to ensure that all homes undergo a 'whole house' energy efficiency programme by 2030.

In September 2009 uSwitch.com's latest Customer Satisfaction Report stated that only 52% of all customers in the Great Britain market are satisfied with the quality of service provided by their energy supplier (although the Report stated that 73% of SSE's customers are satisfied).

Against this background, SSE's objective is to retain and gain energy supply customers by:

SSE continues to believe that it should not seek to build its energy supply business by simply selling more of its core products of electricity and gas. Its focus must be on providing the energy and the related products and services that people actually need in a higher-price, lower-carbon environment, and thereby increasing customer numbers in a sustainable way.

Energy Supply Operations - Customer Numbers

SSE supplies electricity and gas in Great Britain as Southern Electric, SWALEC, Scottish Hydro Electric and Atlantic Electric and Gas. During the six months to 30 September 2009, it achieved a net gain of 100,000 energy supply customer accounts, taking the total to 9.15 million. This is the eighth successive year in which SSE has achieved a net gain in energy supply customer numbers and it has more than doubled its total number in that period. The total comprises:

Within the total, 2.8 million customer accounts are for 'loyalty' products such as energyplus Argos, which rewards customers with money-off discount vouchers, and energyplus Pulse, under which customers are able to support the British Heart Foundation.

In October 2008, SSE and Marks & Spencer (M&S) launched a new dual fuel product under the brand name M&S Energy. The product is available to M&S customers exclusively through M&S' stores and website, and by 30 September 2009 had attracted 123,000 customer accounts. M&S Energy's primary focus is on helping customers to reduce their own energy consumption and it will be developing additional services and energy products to help customers deliver significant and longer-term savings in energy use at home.

Energy Supply Operations - Prices in Great Britain

Over the past few years, SSE has maintained a responsible pricing policy, seeking to delay for as long as possible any increases in prices and seeking to implement as quickly as possible any reductions - all with the objective of providing consistently competitive prices over the medium term, which protect customers from the full impact of volatile wholesale prices.

Since the start of 2004, typical customers of SSE have paid an average of around £500 less for their electricity and gas than have customers of the UK's largest energy supplier, British Gas (based on paying quarterly and averaged across all regions of Great Britain).

SSE reduced its prices for domestic electricity and gas customers on 30 March 2009. In September 2009, Ofgem published its third Quarterly Wholesale/Retail Price Report. Amongst other things, the report concluded that suppliers' gross margin (from which they must meet operating, bad debt and social costs) are projected to increase by around £60 per dual fuel customer over the next year, although it did not take account of extra costs associated with balancing the electricity system and it also under stated the risks associated with buying energy some time in advance of its consumption. At the same time, it did correctly point out that wholesale energy costs are expected to start rising again from the second quarter of 2010. In addition, suppliers face rising network and environmental costs.

In the six months to 30 September 2009, SSE's gas supply business, Southern Electric Gas, traded at a loss. In addition, the higher forward annual wholesale prices and higher distribution and environmental costs all counter the recent falls in wholesale prices for energy. Therefore, while SSE would like to follow the reduction in energy prices it implemented in March with a further reduction if it were possible, it is not able to commit to do so. It remains committed, however, to ensuring its prices and, more importantly, bills, are as low as possible over the medium term. Given the upward pressures on energy prices, avoiding an increase between now and the end of 2010 remains an important goal.

The outlook for energy prices is underlined by the fact that later this month, SSE will launch a new product, which will enable customers to 'fix' the price of their electricity and gas at around 5% below current standard tariff prices until August 2011.

In the meantime, Ofgem's Review of vulnerable customer disconnections, published in October 2009, confirmed that energy suppliers' procedures to protect vulnerable customers from being disconnected are satisfactory and that disconnections themselves remain at historically low levels (affecting around 0.01% of customers).

Energy Supply Operations - Bills in Great Britain

There is, of course, a distinction between the price of a unit of energy and the amount that customers pay for heating and powering their homes. It is clear that the co-operation seen in recent years between government, energy suppliers, Ofgem, consumer organisations and others, and the associated investment, is delivering a sustained reduction in the amount of gas being consumed in Britain's homes.

As a result of this, SSE believes that the fall in domestic customers' demand for gas since 2006 has reduced the average gas bill for an SSE customer by around £120 per annum. Households are, therefore, less exposed to the impact of high prices than they otherwise would be, because they are using less energy, and building on this must be a top priority in the future.

Energy Supply Operations - Smart Meters

'Smart' metering is an emerging system that enables the quantity and value of electricity and gas used by the customer to be continuously monitored and allows information about its use and cost to be available to the customer and exchanged with the supplier, through two-way electronic communications.

In its UK Low Carbon Transition Plan in July 2009, the UK government said: 'Smart meters are key to revolutionising customer service and maximising energy saving. The government has committed to mandating smart meters and has set out an indicative timetable for getting smart metering to all homes by 2020.'

SSE is a leading participant in the UK government-sponsored Energy Demand Reduction Project (EDRP), in which smart meters are the subject of a trial, and in 2008/09 it installed around 9,000 smart meters in homes in Perthshire, Oxfordshire and in south Wales. Evaluation of the latest set of results from the EDRP is still at an early stage, but SSE believes that they indicate that significant savings in energy usage can be achieved by customers with smart meters, adding to the weight of evidence in support of the scope for smart meters to help transform energy consumption.

Energy Supply Operations - Debt

Around 58% of SSE's domestic electricity and gas accounts are paid by direct debit or standing order. A further 11% are paid through pre-payment meters (PPMs) and the balance are on credit terms and settled by cheque or other such payment methods. According to Ofgem's Energy Supply Probe, published in October 2008, 43% of energy accounts in Great Britain are settled using direct debit and 16% are settled through PPMs, with the balance using standard credit terms.

As at 30 September 2009, the total aged debt (ie debt that is overdue by more than six months) of SSE's domestic and small business electricity and gas customers was £102.7m, compared with £73.2m in September 2008, an increase of 40%. A bad debt-related charge to profits of £42m has been made. This comprises a £17m increase in the energy supply bad debt provision and £25m of debt write-off and compares with a charge of £14m in the same period last year.

At the start of this financial year, leading indicators, such as the number of payment reminders being issued to customers, suggested that 2009/10 would pose significant debt management challenges, and the volume of work in this area for the Customer Service division has increased significantly. This has included intervening earlier, when it becomes apparent that customer payments are in arrears, so that the individual's issues are more manageable from everyone's point of view. Nevertheless, with further increases in unemployment likely, there is a significant risk that aged debt will go up further in the months ahead.

Energy Supply Operations - Customer Service

It is no coincidence that SSE has achieved eight years of growth in energy supply while being independently and consistently recognised as the customer service benchmark for the rest of the industry. SSE believes that its proposition for customers needs to include service and products, as well as price, to ensure it offers the best possible value for money.

In total, SSE's energy supply customers made 10.2 million calls to the company during the six months to 30 September 2009, an increase of 12% on the previous year.

In the latest independent Customer Satisfaction Report from uSwitch.com, published in September 2009, SSE was ranked the best energy supplier for the sixth successive time. uSwitch.com stated: 'SSE remains the customer service benchmark for the rest of the industry.' In JD Power and Associates' recently-published 2009 UK Electricity and Gas Supplier Customer Satisfaction Study, SSE's four supply brands took four of the top five places in electricity supply and gas supply, with its Atlantic brand ranked first in electricity.

Following the Consumer, Estate Agents and Redress (CEAR) Act 2007, new arrangements have been put in place under which customers who are unable to resolve issues with their supplier can take them up with Consumer Direct. Complaints which are not resolved within eight weeks, or which become 'deadlocked', may be taken to the new Energy Supply Ombudsman. During the six months to 30 September 2009, there were 478 SSE-related complaints and referrals to Consumer Direct and the Ombudsman. This was a fall of around one third and was the lowest number for any supplier.

The changing shape of customer service is also illustrated by the fact that email has overtaken letters to become the second most common means of communication with the company used by SSE's customers, and around 15% of all customer transactions now take place online. This, in turn, indicates that the popularity of e-services such as paperless billing is likely to increase rapidly over the next few years, and providing the infrastructure to allow customers to carry out more transactions online if they choose is now one of SSE's top customer service priorities.

Energy Supply Operations - Energy Efficiency

Using energy more efficiently is the fastest and most cost-effective means of reducing customers' energy costs, sustaining supplies for the long term and securing reductions in emissions of carbon dioxide. SSE has obligations under the Carbon Emissions Reduction Target (CERT) scheme to deliver energy efficiency measures to households throughout Great Britain and in the six months to 30 September 2009 funded the installation of cavity wall insulation in 58,000 homes and loft insulation in 61,000 homes (excluding DIY insulation).

In September 2009, SSE started a project with Camden Council and Avalon Abseiling in which abseilers were used to access and insulate cavity walls for the first time. The method was developed as a cost-effective and easy way to insulate high rise tower blocks. SSE provided more than £100,000 for the cost of insulating the initial 150 homes as part of the CERT scheme. Insulating the homes by abseiling is about 40% cheaper as there will be no need to pay for scaffolding. The cavity wall insulation by abseiling will be implemented for high rise homes across the borough, and could be adopted by social landlords throughout the country.

In its CERT Annual Report 2009, a review of CERT in 2008/09, Ofgem stated that SSE had met half of its overall carbon emissions reduction obligation for the three years to 2011. SSE also achieved the highest level of solid wall insulation for hard-to-treat properties among all of the obligated energy suppliers.

To complement its heat and energy efficiency strategy, the UK government is also developing a Community Energy Saving Programme (CESP), which aims to deliver energy efficiency measures on a community basis, and has implemented a 20% increase in suppliers' CERT obligations. The CESP will promote a 'whole house' approach, to be delivered through the development of community-based partnerships involving local authorities and energy suppliers via a house-by-house, street-by-street approach. SSE endorses this approach and is actively preparing for the launch of CESP in 2010.

CESP and CERT are substantial measures, which will require the commitment of significant resources by energy suppliers in the coming years. Nevertheless, SSE supports the goal of securing substantial savings in energy bills and reductions in emissions of carbon dioxide, and achieving greater energy efficiency continue to be the most sustainable way of achieving this.

Energy Supply Operations - Vulnerable Customers

While any type of poverty, including fuel poverty, fundamentally results from an individual or household having insufficient income, SSE recognises that it has a significant role to play in helping customers use energy as efficiently as possible and a role also in helping those of its customers who struggle to pay for their basic energy needs.

In April 2008, SSE published its Code of Practice for Fuel Poor Customers, following consultation with consumer and voluntary organisations. At the heart of its approach is the energyplus care tariff, which currently gives eligible dual fuel customers a discount of one fifth compared with SSE's standard tariff, as well as other help including benefit entitlement checks and free energy efficient appliances and home insulation. The number of customer accounts benefiting from energyplus care increased by 23,000 to 126,000 in the six months from April 2009.

SSE will issue credits worth a total of almost £3.5 million to its 290,000 customers who use gas pre-payment meters . The credits are equivalent to suspending the average extra charge its pre-payment tariff contains, compared with SSE's standard credit gas tariff, from 1 November 2009 until 31 March 2010. There is no extra charge on SSE's electricity prepayment tariffs, which were equalised with its standard credit tariffs in 2006.

Under its voluntary agreement with the UK government, SSE expects to operate schemes to help vulnerable customers with a value of around £22m in 2009/10, up from £16m in the previous year. As a result, it is reviewing its approach to enable it to help more customers and is introducing a 'tiered' approach to assistance, allowing a larger number of customers to be helped than would be the case if the 'flat rate' energyplus care tariff was maintained.

It is SSE's policy to do all it can to help customers who may be having difficulties in paying for the electricity and gas they use by offering 'tailor-made' payment arrangements that suit their needs and their circumstances. In September 2009, customers with around 250,000 electricity and gas accounts were taking advantage of these arrangements.

Product Development

Energy supply remains intensely competitive and gaining and retaining customers' loyalty is key to long-term success. At a time of higher energy prices, the 'better plan' is at the centre of the portfolio of products and services which SSE currently markets. It offers a variety of incentives to help customers use less energy and earn credits as a result. The credits are then applied as a reduction to the customers' energy bills.

SSE launched the 'better plan' towards the end of 2007 as part of its commitment to work in partnership with its customers to help them reduce their energy use and to create a more sustainable level of energy consumption. During the six months to 30 September 2009, customers with an additional 44,000 energy accounts joined the 'better plan', taking the total to 178,000, making it SSE's most successful new product ever.

During the current financial year, SSE has launched 'Go Direct', an online energy offer which is available directly from SSE and features a discount equivalent to commission that would otherwise be paid to price comparisons websites and a £40 joining bonus towards bills. Later this month, SSE will launch a new product, which will enable customers to 'fix' the price of their electricity and gas at around 5% below current standard tariff prices until August 2011.

Ireland

At its half-year results in 2007, SSE said it had identified Ireland as a market where the skills honed in Great Britain could be successfully deployed, giving it additional headroom for expansion.

In the six months to 30 September 2009, SSE, through Airtricity, increased its customer base in the all-island electricity market in Ireland by 100% to 100,000. This makes SSE the third largest energy supplier in the Republic of Ireland and the fourth largest in the all-island market.

The profile of Airtricity as a supplier of energy in Ireland will be significantly enhanced by SSE's acquisition of the assets of ESB Contracts, the street lighting business of ESB (see 'Street Lighting' below). It currently maintains around 300,000 street lights in the Republic of Ireland.

NETWORKS

Networks Overview

SSE owns Scottish Hydro Electric Transmission, Scottish Hydro Electric Power Distribution and Southern Electric Power Distribution which transmit and distribute electricity to 3.5 million businesses, offices and homes via 127,000km of overhead lines and underground cables. It also has an equity interest of 50% in, and provides corporate and management services to, Scotia Gas Networks, which distributes gas to 5.6 million properties via 74,000km of gas mains.

SSE estimates that the total Regulated Asset Value (RAV) of these economically regulated 'natural monopoly' businesses, including 50% of SGN, is around £4.8bn. On this basis, SSE is the second largest distributor of energy in Great Britain, with around 12% of the total electricity transmission and distribution RAV and around 13.5% of the total gas distribution RAV.

Over the last three financial years, Energy Networks have contributed just under 40% of SSE's operating profit, in line with SSE's goal of maintaining a balanced range of regulated and non-regulated energy-related businesses. With major investment requirements over the next few years, not least in providing the infrastructure to accommodate electricity produced from renewable sources, the scope for additional incremental growth in Energy Networks businesses is clear. Should opportunities arise to supplement that growth through the acquisition of additional networks, SSE will examine them carefully. It will not, however, depart from its long-stated financial principle of deploying a selective and disciplined approach to acquisitions.

After electricity and gas, telecoms is SSE's third networks business. Unlike the others, it is not the subject of economic regulation. It operates a national telecoms network, offering capacity and bandwidth services for commercial and public sector customers, which extends to around 10,300km throughout Great Britain.

Energy Networks Performance Overview

Operating profit* in Energy Networks increased by 8.7%, from £259.3m to £281.9m, contributing 48.7% of SSE's total operating profit*. This comprised:

Energy Volumes

The volume of electricity distributed by SSE during the six months to 30 September 2009 was around 4% lower than in the same period in 2008, and the volume of gas transported by SGN during the year also fell, by around 14%. These movements should be seen in the context of reductions in national demand of around 5% for electricity and 15% for gas.

Energy Networks Key Performance Indicators Sept 09 Sept 08

Electricity network Regulated Asset Value (RAV) - £bn 2.9 2.8
Gas network RAV (share) - £bn 1.9 1.8
Total RAV of energy network assets £- bn 4.8 4.6
Electricity network capital expenditure - £m 157.9 157.4
Gas network capital/replacement spend (share) - £m 104.7 79.9
Telecoms network (km) 10,300 8,000

SEPD customer minutes lost 30 31
SEPD customer interruptions 30 33
SHEPD customer minutes lost 32 31
SHEPD customer interruptions 34 38
Uncontrolled gas escapes attended within one hour 99.4% 99.1%

VOLUME (TERA WATT HOURS - TWh)
SEPD electricity units distributed 15.3 15.8
SHEPD electricity units distributed 3.6 3.7
Gas volume distributed (Scotland) 17.4 19.7
Gas volume distributed (Southern) 30.0 35.6

Electricity Networks

Southern Electric Power Distribution

In Southern Electric Power Distribution (SEPD) in the six months to 30 September 2009:

The increase in operating profit reflects changes in the price of units distributed, which have mitigated the reduction in volume. Performance in respect of both minutes lost and interruptions was ahead of the targets set by Ofgem under its Quality of Service Incentive Scheme (QSIS), which gives financial benefits to distribution network operators that deliver good performance for customers. Performance-based income covers a number of issues, including the quality of service provided to customers and innovation.

Scottish Hydro Electric Power Distribution and Scottish Hydro Electric Transmission

In Scottish Hydro Electric Power Distribution (SHEPD) in the six months to 30 September 2009:

While there was increased transmission income, this was outweighed by a reduction of income in the distribution business. Performance in respect of both minutes lost and interruptions was ahead of Ofgem's QSIS targets.

Operational Cost Efficiency

Efficiency is one of SSE's core values and amongst Ofgem's explicit purposes in setting Price Controls for regulated network businesses is to keep the costs of providing secure and reliable networks as low as possible. Ofgem's Initial Proposals for the electricity Distribution Price Control Review for 2010-15, published in August 2009, showed SSE consistently at the forefront of efficiency for overall operating costs.

Corporate Responsibility

In August 2009, SSE received an award of £200,000 under Ofgem's Customer Service Reward Scheme 2008/09 'in recognition of the breadth of its corporate responsibility programme which was seen to go beyond core business drivers'.

Electricity Network Investment and RAV Growth

The key responsibility of SSE's electricity networks businesses is to maintain safe and reliable supplies of electricity and to restore supplies as quickly as possible in the event of interruptions. The Distribution Price Control Review for 2005-10 resulted in substantially increased allowances for capital expenditure to maintain and improve the networks' performance. By earning a return from this investment, SSE is able to increase its revenue from the networks and the efficient delivery of this enhanced investment programme has been and remains one of its key priorities.

Capital expenditure in the electricity networks during the six months to 30 September was £157.9m, and a further £165m is expected to be invested by the end of the current financial year. Since the start of the current Distribution Price Control which began in April 2005, SSE has invested £937.9m in its distribution networks (which excludes metering) and a further £175.6m in its transmission network. This represents an 84% increase compared with the same period in the previous Price Control, April 2000 to September 2004.

SSE forecasts that the total growth in the RAV of its electricity distribution and transmission businesses, over the five years to March 2010, should reach around £500m, taking it to almost £3bn in 2010.

Distribution Price Control Review 2010-15

Work on the Distribution Price Control Review for 2010-15 is at an advanced stage, with Ofgem's Initial Proposals in August 2009 being updated in both September and October and with Final Proposals scheduled to be published in December 2009. Ofgem's key priorities are 'to boost customer service and cut carbon from regional electricity networks'.

SSE will assess Ofgem's Final Proposals against three key criteria:

Work on the Distribution Price Control Review will be largely unaffected by Ofgem's review of the regulatory regime for electricity and gas networks ('RPI-X@20'), which is considering the new challenges faced by energy networks as a result of the need to meet environmental and social goals while ensuring continued reliable supply as the move to a lower carbon economy gathers pace. The outcome of Ofgem's review will be subject to consultation.

Electric Vehicles

Electric vehicles will be an essential part of the move towards a low-carbon transport infrastructure. The next decade is likely to see a significant uptake of electric vehicles, which some reports have suggested could reach around 1.5 million in the UK as early as 2020. They also have the potential to dramatically influence the demand profile and quantity of electricity required by consumers, and will impact on all aspects of SSE's business, including electricity distribution.

SSE is part of two consortia that will be conducting research and demonstration projects of prototype electric vehicles over the next twelve months. Both projects are supported by the Technology Strategy Board (TSB):

Future Transmission Developments

Scottish Hydro Electric Transmission (SHETL) is responsible for operating, maintaining and investing in the transmission network in its area, which serves around 70% of the land mass of Scotland. As the licensed transmission company for the area, SSE has to ensure there is sufficient network capacity for those seeking to generate electricity from renewable sources. This presents SHETL with major incremental investment opportunities.

In November 2009, Ofgem announced that it is minded to allow funding for three onshore transmission projects in the SHETL area - Knocknagael, Beauly-Blackhillock-Kintore and Beauly-Dounreay - with a total value of almost £200m. These projects are all designed to accommodate output from renewable energy and should all be completed in 2014.

The project to replace the electricity transmission line connecting Beauly in the Highlands and Denny in the Central Belt of Scotland follows on from SSE's licence responsibilities. The Scottish government has said that Ministers expect to take a final decision on the proposal to replace the Beauly-Denny line, of which 200km is in SSE's SHETL area, 'later this year'. In August 2009, the Marine Energy Group of the Forum for Renewable Energy in Scotland said 'it is essential that the Beauly-Denny link must be consented urgently by Scottish Ministers'. Preparatory work to allow a prompt start to the pre-construction phase, should consent be granted, is continuing.

The final cost of replacing the Beauly-Denny line will be established after the conditions associated with consent from Scottish Ministers, should it be forthcoming, have been considered in detail. SSE will then have to demonstrate to Ofgem that the costs are necessary, efficient and economical so that the resulting charges levied on users of the network are acceptable. It currently expects to invest over £300m to complete its part of the upgrade.

SSE's proposal for an electricity transmission connection between the Western Isles and the north west of Scotland features, for the mainland section, an underground cable between the west coast of Sutherland and the Beauly substation near Inverness. SHETL submitted to Scottish Ministers an application for consent to construct the connection in October 2008.

In July 2009, SSE submitted planning applications for converter stations associated with the proposed subsea high voltage direct current (HVDC) transmission link between the Shetland Islands and mainland Scotland to accommodate renewable energy developments in Scotland. It would connect properties in Shetland to the mainland electricity network for the first time.

SSE has applied to the European Economic Plan for Recovery for funding to support the development of an intermediate offshore HVDC 'hub' off Caithness on the route of its proposed HVDC connection between Shetland and Moray on the Scottish mainland. Following a positive evaluation and ranking by the European Commission, SSE has been invited to take part in formal funding negotiations with representatives of the Commission. Subject to that process, and subsequent approval by the Commission and European Parliament, it is hoped that a grant agreement will be concluded by the end of the year for up to EUR75m towards the cost of the incremental works.

Ofgem and the UK government have created a new regulatory regime for the offshore transmission network needed to connect new offshore wind farms to the mainland electricity network and SSE is considering whether it should participate in the related tender process.

Gas Networks

Scotia Gas Networks (SGN) - Financial

SSE's share of the adjusted operating profit* of SGN was £99.5m in the six months to 30 September 2009, compared with £75.4m in the previous year. The increase is primarily due to three things: the impact of the price changes agreed as part of the five-year Price Control to March 2013, which accounted for the majority of the year-on-year improvement; additional underlying operational efficiencies achieved during the year; and a reduction in the amount and value of gas lost during the distribution process ('shrinkage'). A small part of SGN's operating profit is derived from the non-regulated activities of its contracting, connections and commercial services operations.

In October 2009, SGN successfully priced two new sterling bonds: a 30year, £125m index-linked bond; and a 9 year, £300m fixed-rate bonds.

Scotia Gas Networks - Operational

One of the conditions in SGN's license to operate is that it should attend at least 97% of uncontrolled gas escapes within one hour of notification. During the six months to 30 September 2009, 99.4% of uncontrolled gas escapes were attended within one hour of notification.

During the six months, SGN's gas transportation volumes were:

Only 3.5% of SGN's income is volume-related; the remaining 96.5% is related to the maximum capacity requirements of its customers.

Scotia Gas Networks - Investment

The five-year Gas Distribution Price Control, which began in April 2008, provides the opportunity for SGN to increase significantly investment in its gas distribution networks, thereby reinforcing their safety and reliability and securing another significant increase in their RAV. By 2013, SGN estimates that its total RAV will be around £4.6bn.

In the six months to 30 September, SGN invested £209.4m in capital expenditure and mains and services replacement projects, compared with £159.8m in the previous year. The majority of the mains replacement expenditure was incurred under the 30:30 mains replacement programme which was started in 2002. This requires that all iron gas mains within 30 metres of homes and premises must be replaced over a 30-year period, and during the six months SGN replaced over 500km of its metallic gas mains with modern polyethylene pipes.

Construction of the £50m infrastructure project to build 23km of medium pressure gas main between Farningham and Hadlow is now complete. The pipeline is to maintain gas supplies safely and reliably following recent increases in the demand in the south east of England.

SGN now has approval to commence work on a £20m project to replace the under-sea gas main between the south coast mainland and the Isle of Wight. The project involves the longest directional drill ever undertaken, connecting the 3.8km across the Solent between Lepe and Gurnard. Two tunnels will be bored to take two 12 inch diameter gas pipes, which will be installed some 30m below the seabed.

SGN is committed to making new gas connections to existing homes that are not on mains gas as affordable as possible and is running a new scheme to help fuel poor customers. Already some 2,500 acceptances have been received to provide a mains gas connection to homes under the new Ofgem-approved scheme. One of the first communities to benefit was Rattray in Perthshire where, thanks to an extension to the gas network, some 300 homes will now have access to mains gas, giving residents the choice of gas-fired heating for the first time.

This scheme, along with other initiatives on carbon monoxide safety and reducing environmental impacts, helped SGN secure a £550,000 award from Ofgem under its first ever discretionary rewards scheme for the UK's gas distribution networks. The scheme, which is judged by a panel of industry experts, was established as part of Ofgem's gas distribution price control 2008/13.

Investment will continue to be a top priority and, in line with that, SGN expects to invest a further £195m in capital expenditure and mains and services replacement projects by the end of the financial year.

Telecoms Networks

SSE's combined Telecoms business achieved an operating profit* of £8.2m during the six months to 30 September, compared with £8.1m in the previous year. This reflected a strong sales performance and greater success in retaining customers. In the six months to 30 September 2009, SSE undertook capital expenditure of £7.3m in respect of its telecoms networks, principally focused on improving network reliability and reach.

SSE completed the acquisition of a Fareham-based data centre business in June 2009. It provides capacity for more than 2,000 racks for the co-location of IT services within the 80,000 square feet secure site and 15MW of power in a resilient and energy efficient environment, which will include one of the UK's largest rooftop solar photovoltaic installations. The data centre uses a modular design which allows customers to select the level of service that they require.

Following the acquisition, a trading division, SSE Data Centres, was created, and in October 2009 it was awarded a new long-term contract to provide Kingfisher plc with its own dedicated data centre pod to support IT infrastructure to be migrated from a number of existing data centres.

ENERGY-RELATED SERVICES

Energy-Related Services Overview

As well as being involved in Generation, Supply and Networks, SSE also provides an additional range of energy-related services which complement its other businesses: Contracting, Connections and Metering, including Utility Solutions; Energy and Home Services; and Gas Storage.

Energy-Related Services Key Performance Indicators Sept 09 Sept 08

SEC order book (£m) £102m £105m
New electrical connections 11,000 20,000
New gas connections 3,200 3,800
Out-of-area networks in operation 50 44
Home services customers (inc telecoms) 372,000 283,000
Gas storage net capacity in operation (mcm) 365 325
Gas storage customer nominations met - % 100 100

Contracting, Connections and Metering

Operating profit* in Contracting, Connections and Metering rose by 3.9%, from £40.7m to £42.3m, during the first six months of the year.

Contracting

SSE's Contracting business, Southern Electric Contracting (SEC), operates throughout Great Britain and is one of the largest mechanical and electrical contracting businesses in the UK. Despite the economic recession it has continued to make solid progress during 2009/10, with its order book at 30 September still strong, at £102m, which is just slightly lower than £105m in the previous year. The order book was supported by significant new contract wins with a number of major organisations in recent months, ranging from Network Rail to Exxon Mobil and the University of Bristol.

SEC has continued to benefit from the fact that a major proportion of its business is from public sector bodies and end-user client organisations with a high degree of 'repeat' business or long-term contracts. This puts it in a relatively good position to withstand the economic downturn. Nevertheless, there is clearly a risk that the business' future order book and profitability will be affected as a result of the recession and its consequences. As a result, cost control and customer relationships are a particularly high priority for SEC during 2009/10.

Street Lighting

SEC remains the UK's leading street-lighting contractor, and has 24 maintenance contracts covering over one million lighting columns as at 30 September 2009.

In August 2009, SSE was appointed preferred bidder for the £225m, 25-year South Coast Streetlighting PFI (Private Finance Initiative) contract, through its street lighting business Tay Valley Lighting. Under the contract, SEC will replace and maintain 250,000 streetlights, illuminated signs and bollards on behalf of Hampshire and West Sussex County Councils and Southampton City Council. The contract is expected to be concluded later this year. It will take the number of local authorities with which SSE has long-term street lighting replacement and maintenance PFI contracts to 10 and the number of lighting units covered by such contracts to over 500,000.

In October 2009, SSE entered into an agreement to acquire the assets of ESB Contracts Ltd (ESBC), the street lighting business of ESB, for a total cash consideration of EUR6.4m. The acquisition is due to complete on 30 November 2009. ESBC currently maintains around 300,000 street lights in the Republic of Ireland. Street lighting will in due course become the subject of competitive tendering by local authorities. Under SSE's ownership, the business will be known as Airtricity Utility Solutions and will employ over 100 people, including people who currently work with ESBC.

Electricity Connections

During the six months to 30 September 2009, SSE completed 11,000 electrical connections, compared with 20,000 in the previous year. The reduction was expected as a result of the recession, which has led to a severe downturn in house-building and other construction activity.

Utility Solutions - Electricity Networks

SSE has continued to develop its portfolio of electricity networks outside the Southern Electric and Scottish Hydro Electric Power Distribution areas. It now owns and manages 50 energised electricity networks outside these two areas, including newly-energised networks at Wendover, Stockland Hill and Chappel Level, and there is development work ongoing at a number of these. A further 17 are under construction, including residential and commercial developments across England, Scotland and Wales. In total, SSE now has 430MW of energised networks capacity, plus 71MW currently under construction. Nevertheless, a reduction in new development activity in the UK economy is clearly evident and this will have an impact on SSE's shorter-term growth ambitions in this area, although its market share has been increasing and it expects this to continue.

Utility Solutions - Gas Pipelines

SSE is also a licensed gas transporter, installing, owning and operating gas mains and services on new housing and commercial developments throughout the UK. Although at a slower rate than in previous years, the total number of new premises connected to its gas networks has continued to grow, and during the six months to 30 September 2009, it connected a further 3,200 premises, taking the total number of connections to more than 63,500. This is despite an increasing number of building sites being mothballed, and building projects being deferred, which means the number of gas connections completed in 2009/10 as a whole is likely to be lower than in the previous year.

Utility Solutions - Water

SSE Water (SSEW) is the first new company to offer both water and sewerage services since privatisation in England and Wales in 1989, and its establishment will enable SSE to provide, over the long term, a more comprehensive multi-utility solution to customers in the property development and house-building sectors, through being able to install, own, operate and supply water and sewerage services alongside its existing electricity and gas services.

An 'inset' appointment is the route by which one company replaces another as the appointed water and/or sewerage company for a specified area. SSE Water was granted its first inset appointment in October 2007 to become the water and sewerage provider to a housing development near Salisbury. In March 2009, Ofwat varied the inset appointment of SSE Water, allowing it to serve a large development consisting of houses and commercial premises in south Wales, at Llanilid. SSE has also subsequently been granted two further variations at Tottenham and Reading, bringing the total number of licensed sites to four. SSE has also recently applied for inset appointments in the Ashford and Bromley areas.

Utility Solutions - Energy Services

SSE provides site-wide energy infrastructure for industrial, commercial, public sector and domestic customers. Utility Solutions currently operates and maintains commercial and domestic heating along with a 4.5MW Combined Heat and Power (CHP) facility at Woolwich, and it is developing biomass, heat pump and wind energy solutions for communities and commercial enterprises (most of customers' CHP assets are now managed within SSE's Generation and Supply business). The impact of the economic slowdown on the UK's construction sector means that projects to develop new residential CHP schemes are fewer than was the case a year ago and SSE is now seeking to participate in other sectors such as health, education and defence.

Metering

SSE's Metering business provides services to most electricity suppliers with customers in central southern England and the north of Scotland and has undertaken a programme of in-sourcing of meter reading operations and meter operator work in other parts of the UK. It supplies, installs and maintains domestic meters and carries out metering work in the commercial, industrial and generation sectors. It also offers data collection services to the domestic and SME sectors.

In total, SSE owns 3.79 million meters. During the six months to 30 September, it collected around 3.3 million electricity readings and 1.7 million gas readings, up from 1.4 million and 1.1 million respectively in the same six months in 2008.

This increase partly reflects the fact that, over the past two years, SSE has in-sourced meter reading and meter operations work relating to its own customers in a number of parts of Great Britain. This process has now taken the total number of people employed in the Metering business to over 1,200 as at September 2009 and means SSE is able to read 77% of meters relating to its customers' electricity and gas accounts. This programme of in-sourcing is continuing, so that by the end of 2009/10, SSE expects to be undertaking meter reading and meter operator work in all of the former electricity supply regions in Great Britain.

An accurately-read meter is the cornerstone of good service in energy supply. This programme of in-sourcing delivers significant savings against contractor costs and supports the energy supply brands by delivering improved customer service, partly through the face-to-face contact that takes place between SSE and its customers and partly through the delivery of a more reliable meter reading service. At the same time, it provides a foundation from which SSE will be able to deploy other energy-related services and products as customers increasingly seek help and advice to reduce their consumption of electricity and gas.

Energy and Home Services

Introduction to Energy and Home Services

SSE's energy and home services team offers a range of maintenance and protection services for customers' gas and electrical systems and a full range of gas and electrical installation services. It also offers electricity and gas appliances, telecoms products and community-focused renewable energy schemes.

SSE's 'shield' gas boiler, central heating and wiring protection service is now in its fourth year of operation and at 30 September 2009 had 135,000 customers, an increase of 20,000 during the previous six months. The gas service covers 43 postcode areas, enabling around two thirds of SSE's existing energy customers to benefit from it.

The 'talk' telecoms package, under which telephone line rental and calls services are supplied, now has 237,000 customers, an increase of 20,000 during the previous six months. In March 2009, SSE also launched a new broadband service under which customers are offered unlimited high-speed wireless broadband, supported by a three-year partnership agreed with BT Wholesale.

Sales of electrical and gas appliances have struggled in the light of the recession and in line with the downturn in sales experienced across the retail sector, and this prompted a further reorganisation of SSE's activities in this area. This, unfortunately, included the closure of four shops in the north of Scotland.

Gas Storage

Gas Storage - Financial

Gas Storage delivered an operating profit* of £21.7m, during the six months to 30 September 2009, compared with £21.1m in the previous year.

Gas Storage - Investment

SSE's joint venture with Statoil (UK) Ltd to develop at Aldbrough what will become the UK's largest onshore gas storage facility has made further important progress during the year, with the first commercial operations getting under way. Initially, Aldbrough is providing a total of around 60mcm (million cubic metres) of capacity in two caverns - the first new gas storage capacity to become available in the UK for four years. To form gas storage caverns, salt deposits around 2km under ground are leached by seawater, which, in turn, is replaced (dewatered) by gas under pressure.

The dewatering of another cavern is now complete, and this capacity should become available for storage by the end of this year. The leaching of a fourth cavern is also now complete and dewatering is under way. This cavern should become available for storage in early 2010 and these two caverns will add a further 55mcm of storage capacity. Capacity in a total of six caverns should be available by the end of 2010; in advance of that, storage in some caverns may be unavailable for a short time while their capacity is increased. As stated in its Interim Management Statement in July, SSE expects its total investment on the development at Aldbrough to be around £290m.

When fully commissioned, currently expected to be in 2012, Aldbrough will have the capacity to inject gas and store up to 370mcm (of which SSE will own two thirds) in nine underground caverns and will be the largest onshore gas storage facility in the UK. It will be able to deliver gas to the National Transmission System at a rate of 40mcm per day, equivalent to the average daily consumption of eight million homes, and have up to 30mcm of gas per day injected.

Investment in gas storage in the UK will benefit from the decision by HM Revenue and Customs in April 2009 to recognise the purchase of cushion gas, required to maintain pressure within storage caverns, as part of the capital cost of a development. This means it is eligible for tax relief through plant and machinery capital allowances.

SSE and Statoil (UK) Ltd have consent to increase the storage capacity at the Aldbrough site beyond that currently under development. If developed in full, this would approximately double the amount of gas that can be stored, to well over 700mcm. SSE believes that there is a case for investing in additional gas storage facility and is aiming to take a final decision on whether and how to invest in a second phase of development at Aldbrough during 2010. While the investment decision will be taken on its merits, and in such a way as to ensure there was no detriment to the first phase of the development, an extension at Aldbrough would clearly put SSE at the forefront of new gas storage development in the UK.

Consolidated Condensed Income Statement

for the period 1 April 2009 to 30 September 2009

Six months ending 30 September 2009 2008
Before Exceptional items Total Before Exceptional items Total
exceptional and exceptional and
items and certain items and certain
certain re-measure-ments certain re-measure-ments
re-measure-ments (note 5) re-measure-ments (note 5)
Note £m £m £m £m £m £m

Revenue 4 8,041.8 - 8,041.8 9,187.4 - 9,187.4
Cost of sales (7,241.9) 191.5 (7,050.4) (8,617.3) (177.4) (8,794.7)
Gross profit 799.9 191.5 991.4 570.1 (177.4) 392.7
Operating costs (348.3) - (348.3) (246.0) - (246.0)
Other operating income - - - 10.1 - 10.1
Operating profit before 451.6 191.5 643.1 334.2 (177.4) 156.8

jointly controlled entities and associates Jointly controlled entities and associates:
Share of operating profit 127.3 - 127.3 96.4 - 96.4
Share of interest (45.8) - (45.8) (63.5) - (63.5)
Share of movement on - (0.1) (0.1) - 3.1 3.1

derivatives
Share of tax (14.2) 0.1 (14.1) (7.3) (0.9) (8.2)
Share of profit / (loss) on 67.3 - 67.3 25.6 2.2 27.8

jointly controlled entities and associates
Operating profit 4 518.9 191.5 710.4 359.8 (175.2) 184.6
Finance income 6 80.2 - 80.2 103.8 - 103.8
Finance costs 6 (202.8) (73.4) (276.2) (169.1) 51.8 (117.3)
Profit before taxation 396.3 118.1 514.4 294.5 (123.4) 171.1
Taxation 7 (102.6) (33.2) (135.8) (77.5) 33.9 (43.6)
Profit for the period 293.7 84.9 378.6 217.0 (89.5) 127.5

Attributable to:
Equity holders of the parent 293.0 84.9 377.9 217.7 (89.5) 128.2
Non-controlling interest 0.7 - 0.7 (0.7) - (0.7)

Basic earnings per share 9 41.0p 14.7p

(pence)
Diluted earnings per share 9 40.9p 14.7p

(pence)
Dividends paid in the period 8 425.1 371.0

(£m)

The accompanying notes are an integral part of this interim statement.

Consolidated Condensed Income Statement

for the year ended 31 March 2009

Before Exceptional items Total
exceptional and
items and certain
certain re-measure-ments
re-measure-ments (note 5)
Note £m £m £m

Revenue 4 25,424.2 - 25,424.2
Cost of sales (23,552.7) (1,291.7) (24,844.4)
Gross profit 1,871.5 (1,291.7) 579.8
Operating costs (576.5) - (576.5)
Other operating income - 102.7 102.7
Operating profit before 1,295.0 (1,189.0) 106.0

jointly controlled entities and associates Jointly controlled entities and associates:
Share of operating profit 246.4 - 246.4
Share of interest (128.2) - (128.2)
Share of movement on - 3.8 3.8

derivatives
Share of tax (39.3) (1.1) (40.4)
Share of profit on jointly 78.9 2.7 81.6

controlled entities and associates
Operating profit 4 1,373.9 (1,186.3) 187.6
Finance income 6 209.7 - 209.7
Finance costs 6 (369.8) 25.8 (344.0)
Profit before taxation 1,213.8 (1,160.5) 53.3
Taxation 7 (300.6) 359.6 59.0
Profit for the year 913.2 (800.9) 112.3

Attributable to:
Equity holders of the parent 913.2 (800.9) 112.3
Non-controlling interest - - -

Basic earnings per share 9 12.7p

(pence)
Diluted earnings per share 9 12.8p

(pence)
Dividends paid in the year 8 551.9

(£m)

Consolidated Condensed Statement of Comprehensive Income

for the period 1 April 2009 to 30 September 2009

Year ended 31 March 2009 Six months ended 30 Six months ended 30
September2009 September 2008
£m £m £m
22.9 (Losses)/gains on (21.9) 3.6
effective portion of
cash flow hedges
(6.4) Taxation on cashflow 6.1 (1.0)
hedges
16.5 (15.8) 2.6
(142.9) (Losses)/gain on net (17.1) 11.9
investment hedge
40.0 Taxation on net 4.8 (3.3)
investment hedge
(102.9) (12.3) 8.6
(278.9) Actuarial (losses) (317.5) (191.1)
on retirement
benefit schemes
78.1 Taxation on 88.9 53.5
actuarial losses on
defined benefit
pension schemes
(200.8) (228.6) (137.6)
221.7 Exchange difference (15.2) (0.9)
on translation of
foreign operations
Jointly controlled
entities and
associates:
4.4 Share of 1.9 (2.0)
gains/(losses) on
effective portion of
cash flow hedges
(1.2) Share of taxation (0.5) 0.6
on cashflow hedges
3.2 1.4 (1.4)
(53.2) Share of actuarial (76.4) (46.7)
(losses) on
retirement benefit
schemes
14.9 Share of taxation 21.4 13.1
on actuarial losses
on retirement
benefit schemes
(38.3) (55.0) (33.6)
(35.1) Net share from (53.6) (35.0)
jointly controlled
entities and
associates
(100.6) Other comprehensive (325.5) (162.3)
income
112.3 Profit for the 378.6 127.5
period
11.7 Total comprehensive 53.1 (34.8)
income for the
period
Attributable to:
11.7 Equity holders of 52.4 (34.1)
the parent

as at 30 September 2009

At 31 At 30 September 2009 At 30 September
March 2008

restated
£m Note £m £m
Assets
7,232.2 Property, plant and 7,550.6 6,772.2
equipment
Intangible assets:
724.0 Goodwill 723.0 664.8
253.0 Other intangible 307.8 326.6
assets
918.7 Investments in 956.6 875.1
associates and jointly
controlled entities
18.3 Other investments 8.1 6.7
100.1 Deferred tax assets 167.8 58.7
449.2 Derivative financial 13 436.5 363.7
assets
9,695.5 Non-current assets 10,150.4 9,067.8
213.9 Other intangible assets 196.7 101.9
366.7 Inventories 380.3 335.8
5,659.6 Trade and other 3,442.5 3,298.1
receivables
295.9 Cash and cash 711.4 225.8
equivalents
1,537.7 Derivative financial 13 1,666.2 1,887.8
assets

for the period 1 April 2009 to 30 September 2009

Consolidated Share premium Capital redemption Hedge reserve Retained earnings
account reserve
Reconciliation of movement in Share Equity Translation Non-controlling Total
reserves capital reserve reserve interest
£m £m £m £m £m £m £m £m £m
At 1 April 2009 460.2 835.3 22.0 0.8 19.6 146.6 1,492.7 (2.3) 2,974.9
Profit for the period - - - - - - 377.9 0.7 378.6
Effective portion of changes - - (15.8) - (15.8)
in fair value of cash flow - - - -

hedges (net of tax)
Effective net investment hedge - - - - - (12.3) - - (12.3)

(net of tax)
Exchange differences on - - - - - (15.2) - - (15.2)

translation of foreign operation
Actuarial loss on retirement - - - - - - (228.6) - (228.6)

benefit schemes (net of tax) Jointly controlled entities and associates:
Share of change in fair value - - - - 1.4 - - - 1.4

of effective cash flow hedges
Share of actuarial loss on - - - - - - (55.0) - (55.0)

retirement benefit schemes (net of tax)
Total comprehensive income for - - - - (14.4) (27.5) 94.3 0.7 53.1

the period

Dividends to shareholders - - - - - - (425.1) - (425.1)
Convertible bond converted to 0.9 15.1 - (0.8) - - - - 15.2

equity
Credit in respect of employee - - - - - - 9.1 - 9.1

share awards
Investment in own shares - - - - - - (14.2) - (14.2)
Current and deferred tax - - 0.2 0.2
recognised in equity in - - - - -

respect of employee share awards
At 30 September 2009 461.1 850.4 22.0 - 5.2 119.1 1,157.0 (1.6) 2,613.2
Consolidated Share premium Capital redemption Hedge reserve Retained earnings
account reserve
Reconciliation of movement in Share Equity Translation Non-controlling Total
reserves capital reserve reserve interest
£m £m £m £m £m £m £m £m £m
At 1 April 2008 435.1 315.7 22.0 3.9 2.3 25.4 2,175.6 0.3 2,980.3
Profit for the period - - - - - - 128.2 (0.7) 127.5
Effective portion of changes 2.6 - 2.6
in fair value of cash flow - - - - - -

hedges (net of tax)
Effective net investment hedge - - - - - 8.6 - - 8.6

(net of tax)
Exchange differences on - - - - - (0.9) - - (0.9)

translation of foreign operation
Actuarial loss on retirement - - - - - - (137.6) - (137.6)

benefit schemes (net of tax) Jointly controlled entities and associates:
Share of change in fair value - - - - (1.4) - - - (1.4)

of effective cash flow hedges
Share of actuarial loss on - - - - - - (33.6) - (33.6)

retirement benefit schemes (net of tax)
Total comprehensive income for - - - - 1.2 7.7 (43.0) (0.7) (34.8)

the period

Dividends to shareholders - - - - - - (371.0) - (371.0)
Convertible bond converted to 2.1 36.6 - (1.8) - - (0.6) - 36.3

equity
Credit in respect of employee - - - - - - 6.3 - 6.3

share awards
Investment in own shares - - - - - - (12.7) - (12.7)
Current and deferred tax - - 0.6 0.6
recognised in equity in - - - - -

respect of employee share awards
At 30 September 2008 437.2 352.3 22.0 2.1 3.5 33.1 1,755.2 (0.4) 2,605.0
Consolidated Condensed Statement of Changes in Equity (continued)

for the period 1 April 2009 to 30 September 2009

Consolidated Share premium Capital redemption Hedge reserve Retained earnings
account reserve
Reconciliation of movement in Share capital Equity Translation Non-controlling Total
reserves reserve reserve interest
£m £m £m £m £m £m £m £m £m
At 1 April 2008 435.1 315.7 22.0 3.9 2.3 25.4 2,175.6 0.3 2,980.3
Profit for the year - - - - - - 112.3 - 112.3
Effective portion of changes - - - - 16.5
in fair value of cash flow - 16.5 - -

hedges (net of tax)
Effective net investment hedge - - - - - (102.9) - - (102.9)

(net of tax)
Exchange differences on - - - - (2.4) 224.1 - - 221.7

translation of foreign operation
Actuarial gains on retirement - - - (200.8) (200.8)
benefit schemes (net of tax) - - - -

Jointly controlled entities and associates:
Share of change in fair value - - - - 3.2
of effective cash flow hedges - 3.2 - -
Share of actuarial losses on - - - (38.3) (38.3)
retirement benefit schemes - - - -

(net of tax)
Total comprehensive income for - - - - 17.3 121.2 (126.8) - 11.7

the period

Dividends to shareholders - - - - - - (551.9) (2.6) (554.5)
Premium on issue of shares - 458.0 - - - - - - 458.0
Convertible bond converted to 3.5 61.6 - (3.1) - - - - 62.0

equity
Issue of shares 21.6 - - - - - - - 21.6
Credit in respect of employee - - - - - - 14.3 - 14.3

share awards
Investment in own shares - - - - - - (15.8) - (15.8)
Current and deferred tax - - - (2.7) (2.7)
recognised in equity in - - - -

respect of employee share awards
At 31 March 2009 460.2 835.3 22.0 0.8 19.6 146.6 1,492.7 (2.3) 2,974.9
Consolidated Condensed Cash Flow Statement

for the period 1 April 2009 to 30 September 2009

Year ended 31 March 2009 Six months ended 30 Six months ended 30
September 2009 September 2008
£m £m £m
Cash flows from
operating activities
112.3 Profit for the 378.6 127.5
period after tax
(59.0) Taxation 135.8 43.6
1,265.9 Movement on (118.1) 125.6
financing and
operating
derivatives
369.8 Finance costs 202.8 169.1
(209.7) Finance income (80.2) (103.8)
(81.6) Share of jointly (67.3) (27.8)
controlled entities
and associates
(49.3) Pension service (26.0) (25.3)
charges less
contributions paid
315.9 Depreciation and 173.8 155.9
impairment of assets
14.4 Amortisation and 4.1 6.3
impairment of
intangible assets
8.2 Impairment of - -
inventories
(47.5) Release of - (47.5)
provisions
(16.7) Deferred income (10.3) (7.8)
released
(127.7) (Increase) in (8.6) (84.6)
inventories
(2,048.3) Decrease/(increase) 2,230.1 89.9
in receivables
958.0 (Decrease)/increase (1,513.1) (151.8)
in payables
4.7 Increase/(decrease) (2.6) (6.1)
in provisions
14.3 Charge in respect of 9.1 6.3
employee share
awards
(2.0) Profit on disposal (0.3) (6.1)
of property, plant
and equipment
(102.7) Profit on disposal - -
of 50% of Greater
Gabbard Offshore
Winds
(2.2) Profit on disposal - -
of fixed asset
investment
0.3 Loss on disposal of - -
replaced assets
317.1 Cash generated from 1,307.8 263.4
operations

39.8 Dividends received 7.6 10.6
from jointly
controlled entities
(2.6) Dividends paid to (0.4) -
minority investment
holders
74.4 Finance income 30.5 35.4
received
(219.2) Finance costs paid (154.0) (112.8)
(255.5) Income taxes paid (167.1) (151.9)
(0.4) Payment for - -
consortium relief
(46.4) Net cash from 1,024.4 44.7
operating activities

Cash flows from
investing activities
(1,172.2) Purchase of (524.1) (701.4)
property, plant and
equipment
(37.5) Purchase of other (4.8) (0.3)
intangible assets
24.8 Deferred income 7.8 21.8
received
3.8 Proceeds from sale 31.3 4.0
of property, plant
and equipment
308.5 Proceeds from - -
disposal of 50% of
Greater Gabbard
Offshore Winds
(40.0) Purchase of 50% of - (40.0)
Greater Gabbard
Offshore Winds
2.4 Proceeds from sale - -
of fixed asset
investment
(262.0) Loans to jointly (3.2) (15.9)
controlled entities
(2.1) Purchase of - -
Airtricity
(26.3) Purchase of (56.9) (7.6)
businesses and
subsidiaries
0.1 Cash acquired in 9.7 -
purchases
79.7 Loans repaid by 7.8 20.4
jointly controlled
entities
(44.7) Investment in (12.6) (19.6)
associates and
jointly controlled
entities
(19.7) Investment in (2.8) -
Marchwood Power
(12.5) Increase in other - (0.7)
investments
(1,197.7) Net cash from (547.8) (739.3)
investing activities

Cash flows from
financing activities
479.6 Proceeds from issue - 0.6
of share capital
(551.9) Dividends paid to (425.1) (371.0)
company's equity
holders
(15.8) Employee share (14.2) (12.7)
awards share
purchase
3,203.1 New borrowings 1,323.2 2,773.7
(1,835.3) Repayment of (950.1) (1,746.3)
borrowings
1,279.7 Net cash from (66.2) 644.3
financing activities

35.6 Net 410.4 (50.3)
increase/(decrease)
in cash and cash
equivalents

243.1 Cash and cash 293.6 243.1
equivalents at the
start of period
35.6 Net 410.4 (50.3)
increase/(decrease)
in cash and cash
equivalents
14.9 Effect of foreign (1.2) 19.2
exchange rate
changes
293.6 Cash and cash 702.8 212.0
equivalents at the
end of period

Notes on the Condensed Interim Statements

for the period 1 April 2009 to 30 September 2009

1. Condensed Financial Statements

The financial information set out in these interim statements does not constitute the Company's statutory accounts for the periods ended 30 September 2009, 31 March 2009 or 30 September 2008 within the meaning of Section 240 of the Companies Act 1985. Statutory accounts for the year ended 31 March 2009, which were prepared in accordance with International Financial Reporting Standards as adopted by the EU (adopted IFRS), have been reported on by the Company's auditors and delivered to the Registrar of Companies.

The report of the auditors was (i) unqualified (ii) did not include reference to any matters to which the auditors drew attention by way of emphasis without qualifying their report and (iii) did not contain statements under section 237 (2) or (3) of the Companies Act 1985. The interim financial information is unaudited but has been formally reviewed by the auditors and their report to the Company is set out on page 57.

The financial information set out in these interim statements has been prepared in accordance with IAS 34 Interim Financial Reporting as adopted by the EU.

These interim statements were authorised by the Board on 10 November 2009.

2. Basis of preparation

These condensed interim statements have been prepared applying the accounting policies and presentation used in the Group's consolidated financial statements for the year ended 31 March 2009, except for the impact of the adoption of the Standards and Interpretations described below:

IFRS 8 'Operating Segments', effective for annual periods beginning on or after 1 January 2009, replaces IAS 14, Segment Reporting and requires operating segments to be identified on the basis of internal reports about components of the Group that are regularly reviewed by the chief operating decision maker, which has been identified as the Board. The adoption of IFRS 8 has led to a change in the segmental information disclosed, but has had no impact on the Group's reportable segments or on the reported results or financial position of the group. Further information can be found in note 4.

IAS 1 (Revised) 'Presentation of Financial Statements' is effective for annual periods beginning on or after 1 January 2009. The revised standard prohibits the presentation of income and expense in the statement of changes in equity, requiring non-shareholder changes in equity to be presented separately from shareholder changes in equity. All non-shareholder changes in equity are required to be presented in a performance statement. IAS 1 (Revised) permits a choice as to whether to present a single performance statement (being a Statement of Comprehensive Income) or two statements (being an Income Statement and a Statement of Comprehensive Income). The Group has elected to present two statements. Other changes introduced by the revised standard include a requirement to give the Statement of Changes in Equity equal prominence to the other Primary Statements. These condensed Interim Financial Statements have been prepared under the revised disclosure requirements.

IFRS 2 (Amendment) 'Share-based Payments - Vesting Conditions and Cancellations', this amendment restricts the definition of 'vesting conditions' to a condition that includes an explicit or implicit requirement to provide services. Any other conditions are non-vesting conditions which have to be taken into account to determine the fair value of the equity instruments granted. In the case that the award does not vest as the result of a failure to meet a non-vesting condition that is within the control of either the entity or the counterparty, this must be accounted for as a cancellation. The main impact of this amendment for the Group arises from cancellations by employees of contributions to the Group's Share save schemes; in the event of a cancellation the Group must recognise immediately the amount of the expense that would have otherwise been recognised over the remainder of the vesting period. We have reviewed our Share Based Payments for the amendment and concluded that it has an immaterial impact on previously reported results and balances.

IFRIC 12, 'Service concession arrangements'; this amendment applies to contractual arrangements whereby a private sector operator participates in the development, financing, operation and maintenance of infrastructure for public sector services, for example, under private initiative (PFI) contracts. The Group has contracts with various local authorities under PFI arrangements. These contracts qualify for accounting under IFRIC 12. The adoption of IFRIC 12 has resulted in a reclass from turnover into interest receivable of £0.9m.

The following amendments to existing standards and interpretations were also effective for the current period, but the adoption of these amendments to existing standards and interpretations did not have a material impact on the Financial Statements of the Group.

The following amendments to existing standards and interpretations are also effective for the current period but have not yet received EU endorsement. As such, they have not been adopted by the Group within these condensed interim Financial Statements.

Notes on the Condensed Interim Statements

for the period 1 April 2009 to 30 September 2009

2. Basis of preparation (continued)

At the date of authorisation of these condensed interim Financial Statements, the following standards, amendments to existing standards and interpretations issued by the IASB and IFRIC, which have not been adopted in these condensed interim Financial Statements, were in issue but not yet effective:

The above have not been early adopted by the Group and the impact of adopting these standards and amendments to existing standards is currently being assessed.

Additionally, the following standards, amendments to existing standards and interpretations, which were also in issue at the date of authorisation of these interim condensed Financial Statements but not yet effective and have not received EU endorsement have not therefore been adopted by the Group in these condensed Financial Statements:

In the process of applying the Group's accounting policies, management necessarily makes judgements and estimates that have a significant effect on the amounts recognised in the condensed financial statements. Changes in the assumptions underlying the estimates could result in a significant impact to the statements. The most critical of these accounting judgement and estimation areas are as follows: revenue recognition (energy customers), retirement benefits (IAS 19 measurement), impairment testing (particularly in relation to goodwill), provisions and contingencies and the fair value of IAS 39 financial instruments.

3. Seasonality of operations

Certain activities of the Group are affected by weather and temperature conditions and seasonal market price fluctuations. As a result of this, the amounts reported for the interim period may not be indicative of the amounts that will be reported for the full year due to seasonal fluctuations in customer demand for gas, electricity and services, the impact of weather on demand and commodity prices, market changes in commodity prices and changes in retail tariffs. In Energy Systems, the volumes of electricity and gas distributed or transmitted across network assets are dependent on levels of customer demand which are generally higher in winter months. In Generation and Supply, notable seasonal effects include the impact on customer demand of warmer temperatures in the first half of the financial year and also the related impact of demand on wholesale commodity prices. The impact of temperature on customer demand for gas is more volatile than the equivalent demand for electricity. Other businesses are not considered to be seasonal in nature.

4. Segmental information

The Group has adopted IFRS 8 Operating Segments with effect from 1 January 2009. IFRS 8 requires operating segments to be identified on the basis of internal reports about components of the Group that are regularly reviewed by the chief operating decision maker, which has been identified as the Board, in order to allocate resources to the segment and to assess its performance. In contrast, the predecessor Standard (IAS 14 'Segment Reporting') required an entity to identify two sets of segments (business and geographical), using a risks and rewards approach. Following the adoption of IFRS 8 the Group's reportable segments have not changed.

The Group's reportable segments are the distribution and transmission of electricity in the North of Scotland, the distribution of electricity in the South of England (together referred to as Power Systems), the generation and supply of electricity and sale of gas in Great Britain and Ireland (Generation and Supply). The Group's 50% equity share in Scotia Gas Networks plc, a business which distributes gas in Scotland and the South of England, is included as a separate segment where appropriate due to its significance.

Analysis of revenue, operating profit, assets by segment is provided below. All revenue and profit before taxation arise from operations within Great Britain, Ireland and mainland Europe.

Notes on the Condensed Interim Statements

for the period 1 April 2009 to 30 September 2009

4. Segmental information (continued)

a) Revenue by segment

Year ended 31 March Six months ended 30 September 2009 Six months ended 30 September 2008

Total revenue Intra-segment External revenue Total revenue Intra-segment External revenue Total revenue Intra-segment External revenue
revenue revenue revenue
£m £m £m £m £m £m £m £m £m
Power Systems
292.1 104.1 188.0 Scotland 140.5 43.7 96.8 138.6 48.2 90.4
450.9 204.1 246.8 England 211.6 96.2 115.4 212.0 93.6 118.4
743.0 308.2 434.8 352.1 139.9 212.2 350.6 141.8 208.8
24,366.6 28.9 24,337.7 Generation and 7,535.7 9.9 7,525.8 8,684.9 10.9 8,674.0
Supply
1,077.2 425.5 651.7 Other businesses 548.0 244.2 303.8 494.8 190.2 304.6
26,186.8 762.6 25,424.2 8,435.8 394.0 8,041.8 9,530.3 342.9 9,187.4

Revenue from the Group's investment in Scotia Gas Networks plc, the Group's share being £200.0m (September 2008 - £172.3m, March 2009 - £365.7m), is not recognised as revenue of the Group under equity accounting.

b) Operating profit by segment

Six months ended 30 September 2009
Segment Result JCE / Associate Before exceptional Exceptional items Total
s

COPYRIGHT

Copyright Thomson Reuters 2009. All rights reserved. The copying, republication or redistribution of Reuters News Content, including by framing or similar means, is expressly prohibited without the prior written consent of Thomson Reuters.

Energy regulator Ofgem has proposed funding arrangements of up to £1 billion over the next two years for electricity transmission grid projects that are vital in Britain's bid to combat climate change.

This initiative addresses the need for investment in transmission infrastructure to connect new wind farms and other renewable generation. The regulator has proposed arrangements that are pitched to ensure progress for the most urgently needed projects, while protecting the consumer from unnecessary costs.

The proposed arrangements, could amount to a 20 per cent down payment on the investment needed over the next ten years if all projects meet planning and other criteria for funding. Some 90 per cent of that investment is earmarked for Scotland. This underlines Ofgem's commitment to helping the achievement of sustainable development.

The remaining 80 per cent of the ten-year investment programme will fall into a period of new regulatory controls which come into play when the current controls run out in 2012. Ofgem will decide on arrangements for that investment once the new regime is in place. This will avoid the risk of committing to arrangements that expose consumers to unnecessary costs.

Ofgem chief executive Alistair Buchanan said: "Ofgem has put forward a plan that could inject up to £1 billion into national electricity grid investment. This is needed urgently to handle the growth in wind power and other renewable generation that is arising from Britain's drive to curb climate changing emissions."

Based on the current investment plans of the transmission companies, Government targets for reducing carbon emissions by 2020 could require investment in electricity transmission totalling about £5 billion over the next ten years. Today's proposals could deliver up to a fifth of that sum by 2012 if all projects go ahead.

Meanwhile preparations are underway for the next period of regulatory controls (price controls) for the energy transmission companies. And a project analysing the regime governing all of Ofgem's regulatory controls will conclude in 2010. This project - RPI-X@20 - could change radically the way all networks, including transmission grids, are regulated in future.

Notes to editors

1. The three electricity transmission companies are National Grid Electricity Transmission Limited (NGET), SP Transmission Limited (SPTL) and Scottish Hydro-Electric Transmission Limited (SHETL). They are subject to controls on their revenue (price controls) which are reviewed every five years. The current price control - Transmission Price Control Review 4 (TPCR4) runs to 31 March 2012.

2. Ofgem is in the last stages of a two-year review of the 20-year-old incentive regime that forms the basis of its regulatory thinking. The regime ties revenue and expenditure growth to the retail price index (RPI) plus or minus X percentage points. That scheme has delivered cost reductions and better service to consumers. The review RPI-X@20 will consider all options to make sure the future regime is fit for purpose in the current energy market conditions.

3. The transmission companies have put forward proposals for 20 transmission investment projects spread over the next ten years totalling some £5 billon. They will add more than 60 per cent to the total regulatory asset value of the companies. About £1 billion relates to the transmission companies' latest estimates of costs up to 2012 on projects which could commence construction before the end of TPCR4.

4. Ofgem's initial proposals published today address the need to allow funding of critical projects, while recognising the uncertainty surrounding the need for some of the investments and the prospect of change which may arise as a result of the RPI-X@20 review. Ofgem proposes to fund costs incurred up to the end of TPCR4 in relation to specific projects, with future funding to be addressed as part of the next price control review process. We will continue to scrutinise the case for funding individual projects and review the companies' cost estimates before setting out our final proposals this winter.

5. In determining the scope of funding for individual projects we will consider the prevailing needs for the project and the current state of progress by the transmission company. We propose to identify a list of projects which will be eligible for funding.

6. Ofgem is the Office of the Gas and Electricity Markets, which supports the Gas and Electricity Markets Authority, the regulator of the gas and electricity industries in Great Britain. The Authority's powers and duties are largely provided for in statute, principally the Gas Act 1986, the Electricity Act 1989, the Utilities Act 2000, the Competition Act 1998, the Enterprise Act 2002, the Energy Act 2004 as well as arising from directly effective European Community legislation.

For further press information contact:

Trevor Loveday 020 7901 7288 / 07887 652 252
Chris Lock 0207 901 7225 / 07766 511470

This information is provided by RNS The company news service from the London Stock Exchange

MSCBXLFBKFBZFBZ