Energy professional with 25 years of expertise across the oil, gas, electricity and renewables industry, chiefly by pursuing financial analysis, project development, supply and trading roles in major energy institutions, with extensive knowledge of the energy industry and a network of contacts across regulatory, technical innovation, private investment and end user groups.
Key roles and experiences include:
Private Energy Management Consultant
– Gas and electricity purchasing, long-term contract negotiation and risk-management.
– Commodity and capacity market analysis; administration of trading, supply and billing tasks.
– Due Diligence/M&A analysis relating to UK networks, generation and renewable investments.
– Project development of on-site generation, battery storage and efficiency saving projects.
Head of Gas Trading, Purchasing & Risk-Management at a large integrated energy company– Started up the company’s Gas Trading division in London. Managed around-the-clock department of energy traders and analysts to ensure supply to 3 million domestic and industrial customers.
– Grew gas division to establish the company as the UK’s 2nd largest physical supplier.
– Lead contract negotiator and trader of gas & electricity swaps with £2bn under management.
– Seconded to Corporate Finance team to evaluate network and nuclear electricity investments.
– Handled the company’s dispute resolution case concerning termination of gas and electricity contracts and helped recover circa £200m for the company.
Oil and Gas Field Sales Negotiator & Financial Analyst at a multinational oil and gas company– Negotiated offshore oil, gas and condensate sales, lifting and pipeline access agreements.
– Worked with field partners to manage the company’s equity stake in several gas fields.
– Initiated the company’s UK gas trading operation; undertook financial analysis of North Sea M&A deals, gas storage, interconnector, power generation and industrial gas & power marketing projects.
– Aided in the development of a pan-European strategy and UK gas trading platform.
Oil and Gas Sales Negotiator & Commercial Analyst at a multinational oil and gas corporation– Advised global affiliates on EU regulation affecting exploration, trading & refining businesses.
– Negotiated offshore sales & lifting agreements with equity partners and energy utilities.
– Conducted financial appraisal of investment relating to North Sea exploration, energy storage, interconnector, alternative transport fuels, domestic UK gas and electricity supply ventures.
– Involved in starting up the company’s pan-European Gas Supply and North Sea Spot Trading divisions.
North Sea Oil Operations Controller/Futures Market Analyst at a multinational energy company– Dealt with lifting and shipping operations for the oil supplies of several fields.
– Handled telex operations and prepared market research for 15-Day Brent and Futures trading.
Relevant Educational Background:
Master’s Degree – Economics of Finance and Investment.
Bachelor’s Degree – Economics.
Crude was driven higher over the first quarter amid rebounding global demand for petroleum fuels, geo-political worries over the technical ability of Middle Eastern producers to ramp up supply and new restrictions on Russian exports of oil, gas and refined products.
Whilst new upstream investment by G7 multi-nationals was halted last month, the headline ban hasn’t applied uniformly to existing production activities in Russia. Some principal US and EU energy majors are continuing to produce significant volumes of Russian oil and gas which, one way or another will seep onto world markets, possibly sold at higher final prices if the volumes are now sold through more convoluted supply channels and oligopolistic trading intermediaries.
In order to counteract rising oil prices, the USA on 30th March announced the unprecedented release of a million barrels of crude a day from its Strategic Petroleum Reserve, the most significant stock release since the SPR came about in 1975, in the aftermath of the first oil crisis. Reassuring though this move may sound, the track record of ‘buffer stocks’ in reversing the tide of price is historically poor across commodities markets and if oil should be no exception then the 1 mb/d release could make little or no difference even if it will ease supply in the short run. Conceivably the move could finally make the situation worse by inducing a sense of panic or even suggesting that authorities or ‘those in the know’ are themselves worried and for reasons undisclosed. Going to press, crude prices have since recovered and made up all ground lost in the immediate aftermath of the announcement. Perhaps a further difficulty arises once the 60 day release period is up; not so far off and just at the start of the US gasoline season. In recent years key OPEC+ producers have acted as the world’s ‘production buffer’ and with a fair amount of success at that. Suffice to say that Russian co-operation will be less forthcoming this time around. The crude market looks set to remain choppy, certainly for the immediate foreseeable future. Dated Brent closed the review period up nearly a third, closing just above $105/bbl.
First up it is important to acknowledge that, one month into the crisis, there has been no clear default orphysical disruption to date in relation to Russian gas exports transported to Europe via Ukraine; not by either of the two sides. Above all else is fear of a suspension of supply that has spooked the market, coupled perhaps with many Continental utilities going into winter armed with unusually low storage inventories, recovering gas demand across Europe, sharply rising coal prices and Russian petroleum restrictions themselves rendering all the alternatives more expensive.
Up until now at least, no news had reached the Energy Highlights bunker of any breach in export gas supply terms with swing, take-or-pay and other, counterparty-specific flexibility terms all provided for by Gazprom Neft and Ukrtransgaz alike.
In fact the price matrix above does not tell the full story because, having soared in the immediate aftermath of Russia’s invasion, Forward Year gas prices went on to collapse during much of last month. The bell-weather October Year gas contract actually more than halved at one point in one three week period. Only to recover ground again last week after Russia threatened for the first time to physically halt deliveries of natural gas to west European utilities, unless they now make payments in Roubles. In the event no supply was halted but that is not to say the Russians are simply offering more utilities moretime as behind-the-scenes negotiations continue. If so, then all or some such talks may fail, in which case European buyers may soon face physical restrictions extended to Russian gas in addition to oil & petroleum products.
However, there is a second gas market development. One which may have more significance to the Forward Market in the long run than the threatened restrictions themselves, which hasn’t perhaps been as widely reported as it should have been, which is Russia’s neo-conversion to a Gold Standard such that the rouble is pegged to the dollar-denominated price of gold bullion. This would provide a de facto ‘gold-related ‘floor price’ for the rouble and enable Russia to use its gold reserves (built up extensively over the last few years) to support its currency. It could even serve to increase the cross-correlation between the gold and natural gas markets, especially if European utilities fold and they now agree to pay for their Russian gas supplies in roubles, fixed against gold, in future. If just to defend the petro-dollar’s Trade Currency status in respect of gas, the Federal Reserve and Washington Administration are likely to be putting behind-the-scenes pressure on European utilities and governments to resist this move. This could be part of a wider picture, conceivably with China which has been building up a substantial position in gold of its own.
Gas is fast becoming a pure geo-political power play with consumers caught up in the middle. Completely missing from the Chancellor’s Spring Statement was any mention of extending the price cap to the Industrial & Commercial sector, leaving energy purchasing managers with the headache of having
to decide very soon whether to hedge positions any further or wait in case the market drops down further; mindful that O.T.C. prices possibly stand now at commercially unsustainable levels for their businesses to survive. Things could well start to unravel over the months ahead, barring any significant price shift or intervention of some kind.
Base-load electricity prices initially followed gas prices down last month. It peak price fall – three weeks into March – being closer to 45% compared to 55% in the case of wholesale gas.
But the decline reversed late on in the month. Prices recovered as soaring carbon, coal and gas prices dragged the UK electricity market back up again, closing 5% higher since the start of the year at circa £200/MWh. UK electricity prices are among the world’s most expensive as things stand. However industrial and commercial buyers also face rising non-commodity costs, which are indexed to inflation and will also be rising with green subsidies.
Consequently, forward year contracts that may have been signed in the final weeks leading up to the close of the April Year 2022 Buying Round may prove to be exceptionally expensive for commercial end users, especially those renewing annual contracts roughly 2 to 3 weeks before cut-off, missing out on the sharp retreat in O.T.C. prices just before going out-of-contract.
The one ‘positive’ on offer for users perhaps has been talk of a further renewed push towards renewable electricity and encouragement for mini-nuclear reactors even though no working prototype or final design exists yet. In the event that new renewables and mini-nukes combined do work together to provide the extra peak and base-load volumes needed to offset the fact that the UK will lose the final four of its five operating nuclear reactors 5 years from now, there is the demand impact of the transitionto EV transport, commercial and residential heating electrification to consider. There seems to be no concrete medium-term solution on the table therefore.
Perhaps unsurprisingly, some quite interesting debates and contrasting views are now doing the rounds in energy trading circles. The market fundamentals look precarious in for both fuels. However, barring a change in UK energy policy soon, perhaps the power market is the tighter one. The Russia-Ukraine issue and global gas supply problems may be partially resolved in a year’s time. The power market though faces a seemingly intractable problem of mobilising enough extra carbon-neutral and reliable electricity on time. Consequently, the forward market in electricity looks set to command the higher risk-premium of the two in future and it is already far less liquid than the gas market as things stand. With that in mind, the spark spread could make up much of its lost ground, possibly moving back above £50/MWh and staying there for some while yet.