Full Year Results Introduction
Sir John Parker Chairman
20 May 2010
Full Year Results Introduction Sir John Parker Chairman 20 May - - PowerPoint PPT Presentation
Full Year Results Introduction Sir John Parker Chairman 20 May 2010 Cautionary Statement This presentation contains certain statements that are neither reported financial results nor other historical information. These statements are forward-
Sir John Parker Chairman
20 May 2010
Cautionary Statement
This presentation 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, its results of operations and businesses, strategy, plans and objectives. Words such as ‘anticipates’, ‘expects’, ‘intends’, ‘plans’, ‘believes’, ‘seeks’, ‘estimates’, ‘targets’, ‘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 such as changes in laws or regulations and decisions by governmental bodies or regulators; breaches of, or changes in, environmental, climate change and health and safety laws or regulations; network failure
standards, including delivery of costs and efficiency savings; customers and counterparties failing to perform their obligations to National Grid; and unseasonable weather affecting energy demands. Other factors that could cause actual results to differ materially from those described in this presentation include fluctuations in exchange rates, interest rates, commodity price indices and settlement of hedging arrangements; restrictions in National Grid’s borrowing and debt arrangements; changes to credit ratings of National Grid and its subsidiaries; adverse changes and volatility in the global credit markets; National Grid’s ability to access capital markets and other sources of credit in a timely manner and other sources of credit on acceptable terms; deflation or inflation; the seasonality of National Grid’s businesses; the future funding requirements of National Grid’s pension schemes and other post-retirement benefit schemes, and the regulatory treatment of pension costs; the loss of key personnel or the inability to attract, train or retain qualified personnel; new or revised accounting standards, rules and interpretations, including changes of law and accounting standards that may affect National Grid’s effective rate of tax; incorrect assumptions or conclusions underpinning business development activity, and any unforeseen significant liabilities or other unanticipated or unintended effects of such activities and the performance of National Grid’s subsidiaries. In addition National Grid’s reputation may be harmed if consumers of energy suffer a disruption to their supply. 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). 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 its results to differ materially from those contained in any forward-looking statement. Except as may be required by law or regulation, National Grid undertakes no
Steve Holliday Chief Executive
Financial performance
All business performance figures exclude exceptional items, remeasurements and stranded cost recoveries and are for continuing operations * Recommended by the Board
Operating profit
Profit before tax
Earnings per share
Dividend per share*
Operational performance Safety 40% improvement in Injury Frequency Rate Reliability All UK & US regulatory targets met for the first time Customer satisfaction Some work to do to improve against peers
Delivered priorities for 2009/10
Regulation
Driving efficiency
2009/10 efficiency metric (b) Disciplined investment
delivered in 2009/10, 99% remunerated (c)
(a) 35% of US rate base is currently pending decisions on new rate plans (b) Regulated controllable costs divided by asset base (c) Capital investment for continuing operations, excluding Joint Ventures
Funding UK growth strategy
Maintain single A credit ratings Proven delivery track record
gross proceeds £3.3bn
in next 5 years
Steve Lucas Finance Director
Financial results
Operating profit up 7% Effective interest down to 4.6%* EPS up 14% Dividend up 8%
* Interest rate on treasury managed debt
Transmission
£35m £(33)m £142m £23m £1,464m £1,297m
2009 Net regulated income UK incentive schemes Controllable costs Other, mainly French Interconnector 2010 Operating profit at constant currency
Transmission
(when the average rate was $1.54 to £1.00)
Operating profit
at constant currency share of group
Gas Distribution
£(177)m £1,137m £65m £(19)m £1,268m
2009 UK net regulated income US net regulated income of which £115m is timing Other 2010 Operating profit at constant currency
Gas Distribution
(when the average rate was $1.54 to £1.00)
Operating profit
at constant currency share of group
E, D & G
£258m £1m £35m £374m £80m
2009 Net regulated income Lower storm costs Other 2010 Operating profit at constant currency
Electricity Distribution and Generation
(when the average rate was $1.54 to £1.00)
Operating profit
at constant currency share of group
Non-reg. & other
£30m £17m £29m £5m £146m £65m
2009 Metering Grain LNG Property Other 2010 Operating profit at constant currency
Non-regulated and other
(when the average rate was $1.54 to £1.00)
Operating profit
at constant currency share of group
Real controllable costs(a) reduced by 2% KeySpan synergy savings on track at $159 million Annualised procurement savings in excess of £160 million
Cost savings and efficiency metric
2009/10 efficiency metric(b)
40bps improvement*
£2,110m £2,070m £181m £143m 2008/09 2009/10 Real controllable costs Bad debts
* 2008/09 restated from 8.1% for currency impact, cost reclassifications and Massachusetts gas goodwill adjustment (a) Regulated controllable costs excluding bad debts on a constant currency basis and adjusted for RPI. Constant currency figures calculated by applying the average 2010 rate ($1.58 to £1.00) to 2009 results (when the average rate was $1.54 to £1.00) (b) Adjusted controllable costs (a) divided by asset base. Asset base: mid-year UK regulatory asset value plus US rate base at constant currency.
Earnings, return on equity and dividend
Earnings per share
Group return on equity
Dividend per share
in line with policy
Strong underlying growth Effective interest rate* 4.6% Full year dividend of 38.49p Dividend cover up, at 1.5 times 15% annual return on equity
3-year average
*Treasury managed effective interest rate
£1,494m £1,079m £307m £372m
2009/10 capital investment
Capital investment
2009/10 capital investment: 99% supported by regulatory agreements/long-term customer contracts
Non-regulated & other Electricity Distribution & Generation
Transmission Gas Distribution
Operating cash flow
Net operating cash flow
at actual FX For the year ended 31 March 2010 £m Operating profit 3,121 Depreciation & amortisation 1,188 Pensions (521) Working capital & other 358 Net operating cash flow 4,146
£3,336m £4,146m
2009 2010
Net Debt
Closing net debt
£m Net debt at 1 April 2009 (22,673) Operating cash flow (a) 4,146 Interest & tax (871) Investment (3,176) Dividends (688) Other (b) 383 Net debt before FX (22,879) FX movements 740 Net debt at 31 March 2010 (22,139)
£(22.7)bn £(22.1)bn
2009 2010
(a) Business performance, excluding exceptional items, remeasurements and stranded cost recoveries for continuing operations (b) Includes cash flows relating to exceptional operating items, stranded cost recoveries and other non cash items
Improvement in US outlook
*Nimo electric returns exclude stranded costs
US return (nominal return on equity)
11.3% 10.2%
Allowed Achieved
10.2% 4.5%
Delivering Agreed or under review - too early to contribute to US returns Decisions pending*
US rate base
US rate base
US rate base
14.2% 6.6% 5.05%
Electricity Transmission Gas Distribution Gas Transmission
16.8% 7.6% 5.05% 14.2% 6.3% 4.94%
Good UK operational returns
* Normalised for 3.0% p.a. long run UK RPI
Allowed real vanilla return Achieved real vanilla return Achieved nominal RoE normalised for RPI*
Summary
Steve Holliday Chief Executive
US priorities
NMPC Electric
Massachusetts Gas
requested revenue increases*
Filed – awaiting decision Appropriate structural changes to remuneration framework proposed Effective in second half of 2010/11 Rhode Island Electricity Appeal launched Filing new rate case in second half of 2010/11 New Hampshire Evaluating options for exit
* Figures stated are increases requested in first year
UK energy landscape is changing Existing powerstation closures
Gas from UK sources
Greater clarity on size and timing
Scenario planning ENSG report* New investment regardless of generation mix
* Electricity Networks Strategy Group: “Our Electricity Transmission Network: A Vision for 2020 (Full Report)”
Capital investment increase
Group capital investment
in last 5 years
Good visibility of returns Investment 99% remunerated Transmission price controls Increased allowances up to 2012 Scope for enhanced returns Core investments into RAV Unregulated investments case-by-case
Fully underwritten rights issue
Terms
Basis 2 for 5 New shares 990m Discount to TERP 35.7% Discount to ex. div closing price 43.7% Bonus element of rights 1.1427
Price
Closing price £6.20
£5.95 Issue price for new shares £3.35 Theoretical ex. rights price £5.21 Theoretical nil paid price £1.86
Key terms
£3.3bn gross proceeds (23% of market capitalisation*)
* Market capitalisation ex - dividend
Core license area Specific projects include: ENSG identified electricity transmission infrastructure Upgrades to the gas transmission system New deep tunnel, cable networks in London & Midlands Minimal regulatory lag
Core growth investment
Onshore transmission infrastructure
major asset replacement
Additional UK investment opportunities
Investment opportunities
Pipeline of opportunities New electricity Interconnectors Grain phase IV expansion Offshore electricity transmission networks New CO2 transportation networks Contingent on securing attractive returns
Unchanged dividend policy
Dividend policy to 2012
per annum Dividend policy post 2012
reflecting the growth prospects of the business
Summary & outlook
Strong performance Strategy delivering Confidence in UK growth opportunities Rights issue provides flexibility Disciplined capital investment
Business performance results
8% 35.64p 38.49p Dividend per share 14% 50.2p 57.4p Earnings per share 12% 1,770 1,974 Profit before tax (actual FX) 8% 2,888 3,121 Operating profit (constant FX) 7% 2,915 3,121 Operating profit (actual FX) change 2009 2010 For the year ended 31 March (£m)
* 2008/09 comparative has been restated to reflect the uptake of the 2009/10 scrip dividend (August 2009 – 25% and January 2010 – 20%)
average rate was $1.54 to £1.00)
*
Business performance results and statutory results
37.9p 56.1p Statutory earnings per share 944 1,386 Statutory earnings attributable to equity shareholders (3) (3) Minority interests 947 1,389 Statutory profit 25
922 1,389 Statutory profit (continuing operations) (472) (804) Taxation 1,394 2,193 Statutory profit before taxation (continuing operations) 5 8 Share of post-tax results of joint ventures and associates (1,234) (1,108) Net finance costs (including exceptional items and remeasurements) (292) 172 Exceptional operating items, remeasurements and stranded cost recoveries 2,915 3,121 Operating profit* 2009 2010 For the year ended 31 March (£m)
* Business performance, excluding exceptional items, remeasurements and stranded cost recoveries for continuing
Revenue
15,624 13,988 Total revenue (226) (179) (Sales eliminations) 435 376 Stranded cost recoveries 719 738 Non-regulated businesses and other 4,537 3,963 Electricity distribution (excluding stranded cost recoveries) 4,786 3,708 Gas distribution - US 1,466 1,517 Gas distribution - UK 420 405 Transmission - US 3,487 3,460 Transmission - UK 2009 2010 For the year ended 31 March (£m)
Transmission Depreciation & Amortisation
409 432 Total Transmission depreciation & amortisation 14 11 Sub total – Other 7 4 LNG (storage) 7 7 Interconnectors (UK) 56 59 Sub total – Electricity Transmission (US) 10 10 Interconnectors 27 27 New York Transmission 19 22 New England Transmission 115 123 Sub total – Gas Transmission (UK) 14 14 Gas System Operator 101 109 Gas Transmission Owner 224 239 Sub total – Electricity Transmission (UK) 16 11 Electricity System Operator 208 228 Electricity Transmission Owner 2009 2010 For the year ended 31 March (£m)
Transmission Operating costs (excluding depreciation & amortisation)
2,227 14 (20) 25 9 190 13 96 81 379 8 199 172 1,644 41 1,255 348 2009 1,984 Total Transmission operating costs (excluding depreciation & amortisation) 8 Sub total – Other (25) Internal eliminations 23 LNG (storage) 10 Interconnectors (UK) 193 Sub total – Electricity Transmission (US) 13 Interconnectors 106 New York Transmission 74 New England Transmission 353 Sub total – Gas Transmission (UK) 8 Other gas 192 Gas System Operator 153 Gas Transmission Owner 1,430 Sub total – Electricity Transmission (UK) 42 Other electricity 1,060 Electricity System Operator 328 Electricity Transmission Owner 2010 For the year ended 31 March (£m)
Transmission Operating profit
1,301 1,464 Total Transmission operating profit 72 45 Sub total – Other
LNG (storage) 72 46 Interconnectors (UK) 175 153 Sub total – Electricity Transmission (US) 8 8 Interconnectors 61 40 New York Transmission 106 105 New England Transmission 321 453 Sub total – Gas Transmission (UK) 117 186 Gas System Operator 204 267 Gas Transmission Owner 733 813 Sub total – Electricity Transmission (UK) 1 3 Other electricity 9 52 Electricity System Operator 723 758 Electricity Transmission Owner 2009 2010 For the year ended 31 March (£m)
Gas Distribution
1,284 1,137 Total Gas Distribution operating profit 612 414 Operating profit (US) 672 723 Operating profit (UK) (4,621) (3,715) Total operating costs (excluding depreciation & amortisation) (4,002) (3,121) Operating costs (US) (619) (594) Operating costs (UK) (349) (374) Total depreciation & amortisation (172) (173) Depreciation & amortisation (US) (177) (201) Depreciation & amortisation (UK) 2009 2010 For the year ended 31 March (£m)
Electricity Distribution & Generation
265 374 Total Electricity Distribution & Generation operating profit (4,054) (3,380) Operating costs (excluding depreciation & amortisation) (218) (209) Depreciation & amortisation 2009 2010 For the year ended 31 March (£m)
Metering, Grain LNG and Property
1 (64)
41 21 (40) (13) 74 133 (133) (140) 406 2009 6 Property operating profit (28) Operating costs (excluding depreciation & amortisation)
3 Other operating income 31 Revenue 51 Grain LNG operating profit (56) Operating costs (excluding depreciation & amortisation) (30) Depreciation & amortisation 137 Revenue 162 Metering and Onstream operating profit (122) Operating costs (excluding depreciation & amortisation) (125) Depreciation & amortisation 409 Revenue 2010 For the year ended 31 March (£m)
Exchange rates
(784) Impact on book value of assets 740 Impact on net debt (7) Net impact on earnings 4 Impact on tax, JVs and minority interests 16 Impact on interest (27) Impact on operating profit 2010 For the year ended 31 March (£m) 1.54 1.58 Average $ / £ rate for the period 1.44 1.52 Closing $ / £ rate 2009 2010 For the year ended 31 March (£m)
Pensions & other post-retirement benefit obligations: regulatory recovery principles
Annually Annually 2010 2010 Next actuarial valuation expected (no obligation to fund deficits – standard practice adopted) 100% 100% N/A N/A OPEB costs & deficits recoverable (true-up mechanisms / filings lead to timing variances only) (legacy non-regulated and some ERDC excluded) 100% 100% 63% 98% Deficits recoverable 100% 100% 90% 98% On-going pension costs recoverable OPEBs Pensions NGUK PS ESPS Regulatory recovery principles US UK
pension costs for this purpose are as measured on a US GAAP basis, which includes the amortisation of deficits or surpluses
US pensions & other post-retirement benefit obligations: regulatory treatment by rate plan
Propose reconciliation mechanism in rate case filing in 2010, PUC Staff generally oppose reconciliation New Hampshire Propose reconciliation mechanism in rate case filing in 2010, PUC opposed reconciliation in last case (2009) Rhode Island (electric) Propose reconciliation mechanism in rate case filing in 2010 Massachusetts (Colonial gas, Essex gas) Mechanism Jurisdiction Pension / OPEBs are a component of cost of service used to set rates. Level remains in effect until next rate case with no true-up. Approach 2: Base rates with no true up at FERC but true-up at end of LIPA contract LIPA Generation Formula Rate – monthly reconciliation of actual expenses FERC Annual reconciliation agreed in recent rate case Rhode Island (gas) Reconciliation with deferred amounts collected/ credited over 3 years Massachusetts (Boston gas, MECO) Reconciliation with deferred amounts collected / credited in CTC (deferral account) reset New York Mechanism Jurisdiction Periodic reconciliation of revenues to reconcile to actual pension / OPEB costs. Approach 1: Each of our five US regulatory commissions regulate the level of costs related to pensions and other post-retirement employee benefits (OPEBs) that are charged to customers.
Pensions & other post-retirement benefit obligations: (IAS19 data)
* Taxation is calculated using the UK statutory tax rate and the US tax rate attributable to the combined pension and OPEBs balance at 31 March 2010.
US UK NG total OPEBs Pensions NGUK PS ESPS At 31 March 2010 (£m) 6.1% 6.1% 5.6% 5.6% Discount rates (1,953) (1,025) (462) (111) (355) Liability net of taxation 1,145 661 304 43 137 Taxation* (3,098) (1,686) (766) (154) (492) Net liability (22,234) (2,636) (4,069) (13,506) (2,023) Present value of liabilities 19,136 950 3,303 13,352 1,531 Market value of assets
Timing impacts
13 (3) 38 9 7 (38) 2008/09* over/(under) recovery (163) (41) (77) (19) (8) (18) 2009/10 over/(under) recovery (199) (40) (55) (20) (4) (80) Closing balance to recover (176) (38) (115) (28) (15) 20 Year on year timing variance (27)
Recovery of new licence allowances granted in year (163) (41) (77) (19) (8) (18) 2009/10 over/(under) recovery (9) 1 22 (1) 4 (35) Opening balance Total US UK US UK £m
Gen US Gas Distribution Transmission
* Restated for finalisation of K and change in reporting methodology
Regulated asset base and returns Transmission
Base allowed return Rate base / RAV Achieved return Sharing factors (shareholder retention at RoE) Last / next rate case filing UK electricity transmission (a) New England Power Equity / debt (assumed) UK gas transmission (b) Narragansett electric (Transmission) Canadian Interconnector (c) Regulator
Ofgem £7,500m 5.05% (‘vanilla’ return) 6.6% 40 / 60 100% plus incentive schemes 1 year rollover from April 2012 FERC $861m 11.1% (RoE) 11.8% 65 / 35 100% Monthly formula rates FERC $67m 13.0% (RoE) 13.0% 40 / 60 100%
£4,533m 5.05% (‘vanilla’ return) 7.6% 40 / 60 100% plus incentive schemes 1 year rollover from April 2012 FERC $189m 11.1% (RoE) 11.5% 50 / 50 100% Monthly formula rates
(a) Includes electricity system operator regulatory asset base of £57m. The system operator is subject to annual price controls. (b) Includes gas system operator regulatory asset base of £35m. The system operator is subject to annual price controls. (c) National Grid retains 100% of the return it earns on its stake of ~54% in the Canadian Interconnector. *Details of returns and rate base for all rate plans can be found at www.nationalgrid.com. National Grid’s estimate of US rate base: regulatory filings or an alternative USGAAP invested capital measure where either recent rate base filings are not available or where the actual filed rate base currently excludes certain regulatory asset balances.
Rate base* and returns reported by regulatory entity as at 31 March 2010 and 31 December 2009 for UK and US entities respectively.
Regulated asset base and returns Gas Distribution
Base allowed return Rate base / RAV Achieved return Sharing factors (shareholder retention at RoE) Last / next rate case filing Equity / debt (assumed) Up-state New York (NMPC gas) Regulator UK gas distribution
Ofgem £7,001m 4.94% (‘vanilla’ return) 6.3% 37.5 / 62.5 100% plus incentive schemes New price control from April 2013
Long Island (KEDLI)
New York PSC $1,899m 9.8% (RoE) 10.5% 45 / 55 100% to 10.5% 50% to 12.5% 35% to 13.5% Effective from January 2008
Down-state New York (KEDNY)
New York PSC $2,350m 9.8% (RoE) 11.2% 45 / 55 100% to 10.5% 50% to 12.5% 35% to 13.5% Effective from January 2008 New York PSC $1,103m 10.2% (RoE) 3.8% 44 / 56 100% to 11.35% 50% to 13.6% 25% to 15.6% 10% above 15.6% Effective from May 2009
Massachusetts gas** (a)
Massachusetts DPU $1,536m 10.6% (RoE) 2.9% ~50 / ~50 100% to 14.2% 75% above 14.2% Filing for new rates April 2010
Narragansett gas
Rhode Island PUC $337m 10.5% (RoE) 6.7%(c) 48 / 52 100% to 10.5% 50% to 11.5% 25% above 11.5% Effective from December 2008
Energy North (b)
New Hampshire PUC $193m 9.5% (RoE) 3.8% 50 / 50
rates Feb 2010
Rate base* and returns reported by regulatory entity as at 31 March 2010 and 31 December 2009 for UK and US entities respectively.
(a) Massachusetts gas currently comprises three separate entities: Boston gas, Colonial gas and Essex gas: Base allowed and achieved RoEs are weighed averages (using rate base.) Earnings sharing factors apply to Boston gas only. (b) Energy North temporary rate increase effective June 2010. (c) Stated after normalising for one-time bad debt adjustments *Details of returns and rate base for all rate plans can be found at www.nationalgrid.com. National Grid’s estimate of US rate base: regulatory filings or an alternative US GAAP invested capital measure where either recent rate base filings are not available or where the actual filed rate base currently excludes certain regulatory asset balances. **Rate base now excludes goodwill.
Regulated asset base and returns Electricity Distribution & Generation
Base allowed return Rate base / RAV Achieved return Sharing factors (shareholder retention at RoE) Last / next rate case filing Up-state New York (a) (NMPC elec.) Narragansett electric (Distribution) Equity / debt (assumed) Massachusetts electric (b) Granite State Electric Nantucket electric (c) Long Island Generation (d) Regulator
Massachusetts DPU $1,494m 10.4% (RoE) 4.7% 50 / 50 100% to 10.35% 50% above 10.35% Effective from Jan 2010 $58m 9.7% (RoE) (1.3)% 50 / 50 100% to 11% 50% above 11% Effective from Jan 2008 Massachusetts DPU $16m 10.4% (RoE) 11.0% 50 / 50 Over/ under earning contributed to
Effective from Jan 2010 FERC $503m 10.8% (RoE) 13.5%(e) 50 / 50 Incentives Effective from Feb 2009 New York PSC $3,724m 10.6% (RoE) 5.1% Varied annually 100% to 11.75% 50% to 14% 25% to 16% 10% above 16% Agreed July 2002 Filing Jan 2010 Rhode Island PUC $548m 9.8% (RoE) (2.9)% 43 / 57 100% to 9.8% 50% to 10.8% 25% above 10.8% Effective from Jan 2010 New Hampshire PUC
Rate base* and returns reported by regulatory entity as at 31 December 2009.
(a) NiMo electric rate base excludes $651m of US stranded assets rate base. (b) Massachusetts electric rate base includes $20m relating to transmission assets. (c) Nantucket electric rate base excludes $46m relating to sub-sea cables. (d) Long Island generation rate base includes peaking plant rate base of $129m, also reflected in the achieved RoE. (e) Stated after normalising for one-time Genco settlement adjustments. *Details of returns and rate base for all rate plans can be found at www.nationalgrid.com. National Grid’s estimate of US rate base: regulatory filings or an alternative US GAAP invested capital measure where either recent rate base filings are not available or where the actual filed rate base currently excludes certain regulatory asset balances.
Nominal return on equity for whole group
Adjusted net income divided by equity base UK RAV indexation adjustment to net income causes annual RoE to track inflation 15.0% annualised RoE in 2010
Group return on equity
Three-year average RoE
11.8% 10.8% 11.3% 2008 2009 2010
net debt.
Group RoE (nominal) – calculation
3,199 947 1,389 IFRS statutory net income (1,590) (16)
(96) 587 253 Exceptional items - continuing (3) (3) (3) Minority interests 3.8% (0.4%) 4.4% UK inflation rate 12.2% 6.6% 15.0% Group RoE – nominal (adjusted group profit after tax / group equity value) 11,683 11,264 11,422 Group equity value (16,461) (16,651) (22,673) Adjusted opening net debt 28,144 27,915 34,095 Group enterprise value 71 168 250 Joint ventures 860 770 976 Unregulated businesses (net assets) 11,535 10,046 15,154 US invested capital (excluding stranded costs) 193 115 134 Other UK transmission 15,485 16,816 17,581 UK regulatory asset value 1,424 740 1,711 Adjusted group profit after tax (60) (63) (62) Pension revenue adjustment 572 (63) 766 Indexation of UK regulatory asset value (10) (9)
(118) (147) (179) Regulatory and accounting capitalisation (186) (237) (232) Regulatory and accounting depreciation adjustment 1,226 1,259 1,418 IFRS income excluding US stranded costs (55)
(229) (256) (221) IFRS US stranded costs (after tax) 2008 2009 2010 For the year ended 31 March (£m)
Interest, tax, and exchange rates
Effective interest rate*
down 110bps on prior year (1,155) 2010 (1,150) Net finance cost, actual FX (£m) 2009 12 months ended 31 March
Effective tax rate
down 120bps on prior year (553) 2010 (517) Tax (£m) 2009 12 months ended 31 March
Net currency impact
1.44 1.52 Closing $/£ rate 1.58 2010 1.54 Average $/£ rate for the period 2009 12 months ended 31 March
*Interest on treasury managed debt
Interest cover – calculation
2,045 2,465 2,160 Interest expense (P&L) 119 133 99 Capitalised interest
92 Interest on pensions debt adjustment 4 7 6 Interest on decommissioning liabilities adjustment 3.2x 3.1x 3.9x Interest cover (adjusted funds from operations / adjusted interest expense) 3,618 4,268 4,357 Adjusted funds from operations 110 143 (144) add back cash tax paid (for continuing operations) (125) (16) (395) Prior year adjustment (if negative) 4 (298) 7 (126) 6 124 add back decommissioning liabilities adjustment Corporation tax 63 81 87 add back lease rentals
92 add back interest on pensions debt adjustment 465 799 572 add back employer pension contributions (127) (136) (112) Current pension service cost 150 (54) (431) Working capital adjustment
Dividends received 211 79 24 Interest income on financial instruments 3,165 3,413 4,516 Net cash inflow from operating activities 1,143 1,392 1,123 Adjusted interest expense (45) (68) (70) Unwinding of discounts on provisions (1,001) (1,250) (1,193) Pensions interest on scheme liabilities 21 27 29 Interest on lease rentals adjustment 2008 2009 2010 For the year ended 31 March (£m)
Efficiency metric – calculation
8.0% 7.6% Efficiency: adjusted regulated controllable costs / adjusted regulated asset base 110 112 Depreciation adjustment(g) (419) (435) Depreciation adjustment(d) 26,397 27,417 Total adjusted regulated asset base 9,071 9,309 (234) (255) US capital additions adjustment (at constant currency)(f) 9,195 9,452 US rate base (at constant currency)(e) 17,326 18,108 929 962 UK capital additions adjustment(c) 16,816 17,581 UK regulatory asset value(b) Regulated asset base 2,109 2,070 Adjusted regulated controllable costs (at constant currency, excluding bad debt expense)(a) 2009 2010 For the year ended 31 March (£m)
(a) 2009 constant currency figures calculated by applying the average 2010 rate ($1.58 to £1.00) to 2009 results (when the average rate was $1.54 to £1.00). Note: 2009 figure has been restated for cost reclassifications to present items on a consistent basis with the current year. (b) Opening RAV inflated to mid year prices. (c) Adjustment to reflect mid-year growth in the asset base – adds 50% of the full year UK regulated capital investment. (d) Adjustment to reflect mid-year depreciation – deducts 50% of the full year UK regulated depreciation. (e) Closing rate base as at 31 December. 2009 constant currency figures calculated by applying the average 2010 rate ($1.58 to £1.00) to 2009 results (when the average rate was $1.54 to £1.00). Note: 2009 figure has been restated for a Massachusetts gas goodwill adjustment to present items on a consistent basis with the current year. (f) Adjustment to reflect mid-year growth in the asset base – deduct 25% of full year US regulated capital investment. (g) Adjustment to reflect mid-year depreciation – adds 25% of the full year US depreciation
Rights issue rebasing for future dividends
2009/10 full dividend
2009/10 final dividend recommendation of 24.84p/share
gives full 2009/10 dividend of 38.49p/share
Our 2010/11 full dividend is targeted to grow by 8% following re-basing for the bonus element of the rights issue
1.1427 = 33.68p
Targeted 2010/11 full dividend of 36.37p/share
2008/09 2009/10 Rebased 2009/10 2010/11 2011/12 DPS Pre Rights Issue DPS Post Rights Issue
+8% +8% target 35.64p 38.49p 33.68p 36.37p 39.28p
Rights issue transaction Proposed timetable
Announcement 20 May 2010 Publication of prospectus 25 May 2010 Nil paid trading period 26 May 2010 – 11 June 2010 Final date for acceptances and payment in full 11:00 a.m. on 11 June 2010 Dealings in new ordinary shares, fully paid commences 14 June 2010
5 year capital investment plan c.£22bn
Almost 75% of our investments will be in the UK Over 60% of our investments will be in the Transmission business
73%
73% 27%
UK US
61% 39%
Transmission Other