Pain Likely in 2015, But Deep Water GOM Should Be Better Placed Than Unconventional

Pain Likely in 2015, But Deep Water GOM Should Be Better Placed Than Unconventional

13th December 2014

Significantly reduced cash flow for companies in 2015 means that reprioritizing spending is inevitable.  In the short term there is not always the flexibility to make decisions based solely on fundamentals, and so the first impacts may well include projects that in the long run remain viable.  As a high cost environment, the deep water Gulf of Mexico (GOM) would appear to be vulnerable and, indeed, cuts should be expected there. 

However, economic analysis carried out by Gaffney, Cline & Associates (GCA) suggests that good projects in that environment can still be viable down to US$60 per barrel.  Further, economic rationality would suggest that where the opportunity exists, onshore shale spending would be a better short-term target for capital deferral because operating flexibility allows any adjustments made there to be reversed in equally quick order.  That is not the case in the deep water GOM where it is tomorrow’s expected price that is the key driver, and where deferral now may mean missing out on gains later. 

With oil now trading well below US$70 per barrel from a 2014 high of US$115 in late June, the price slide has been the longest continual month over month decline and the steepest drop since the recession of 2008 during the financial crisis.  Along with the slide in prices, oil companies have watched 10% or more wiped off their market capitalization.  It will come as no surprise to anyone that the fall in oil prices is raising questions as to what impact this is going to have on industry activity in 2015.  Indeed, the key take-away from the recent OPEC meeting is that, through its impact on activity and therefore production, price is the weapon of choice to address the changing balance of supply in a demand-constrained world. 

Activity is driven by a combination of factors: fundamental economics, cash flow and availability of funding, internal project resourcing (people), and commitments already undertaken.  When there is rapid change, it takes a while for the dynamics of this mix to unwind.  Looking at the other end of the spectrum, it was four or five years before the oil price rise that started in 1999 was taken to represent a paradigm shift.  The initial response was for companies to prosper, pay down debt and buy back shares, “not squander it this time”, and be content in the belief that price would revert to the US$20 per barrel mean that it had over the previous 20-25 years.  On the other hand, when the oil priced crashed in 2008, it was only a few months before the response was seen in the rig count (Figure 1); a time lag that is now very similar to when prices started falling this time around.

Figure 1 - Historical crude oil price and US rig count

In 2008, oil price fell US$90 per barrel and the U.S. onshore rig count was down by 1,000 within six months, although then rising again almost as rapidly as prices recovered.  Thus far, in 2014, oil price has fallen by a little less than US$50 per barrel from its June high, with further uncertainty as to exactly where it headed and for how long.  Nonetheless, if 2008 turns out to be a guide then a fall in the order of 500 rigs or more (some 25% to 30% of the rig count) could be the consequence, even though the rig count has only just started to hint at such a fall.  In this vein, DrillingInfo recently reported that November drilling permits in Texas fell nearly 50% compared to October, albeit October had seen a 24% rise over September and permit data has shown volatility in the past making it hard to use as a clear indicator.

Using 2008 as a guide for 2014 is more complex in the GOM as activity at that time was dominated by gas well drilling, and the price of gas which continued falling after oil prices picked up.  Since 2010 (with the hiatus following Macondo) GOM activity has been driven by drilling for oil and deep water.  The problem currently is the uncertainty as to where prices eventually settle, and for how long.  There has been some suggestion that support might come in at around US$60 per barrel, although there has been a jump in options trading for December 2015 at US$35-40 per barrel.  In 2009-2010 the oil price recovery was into the US$70-80 per barrel range until the Arab Spring drove it higher, where it has largely remained until the current fall.  Regardless, it is clear that nothing is presently certain and in terms of 2015 decisions will still need to be taken whether US$70 per barrel or less turns out to be a temporary phenomenon or not. 

Combining therefore the need to address cash flow but not over-react, the focus is likely to be where the impact is more easily reversible should the current price plunge reverse in whole or part.  However, not all decisions will be choices; commitments already entered into will drive actions.  Short-term revenue protection from hedging will allow a few months or a year or so for some activity to continue where otherwise cash flow realities might make any decision moot.   For some companies, in an otherwise healthy position, the fall in prices might actually represent an opportunity, whether to press ahead with an acquisition or a project that might now cost less as construction and manufacturing constraints disappear and costs adjust accordingly.

At the end of October, 2014 GCA posted an article ( looking at the potential impact of US$80 per barrel on activity in unconventional shale oil plays in the United States.  That article indicated that, using the “sweet spot” volatile oil window of the Eagle Ford as an example, activity was still profitable at that price although more fringe areas (and other basins with pricing disadvantages) might be more challenged.  However, even the sweet spots in the Eagle Ford oil window started to look challenged at US$70 per barrel. 

Costs, investment levels and returns for individual companies in the deep water Gulf of Mexico can be comparable with the unconventional, even though the life cycle of each of these types of development projects is quite different.  Figure 2 compares the expected Rate of Return (ROR) of two investment scenarios – one in the deep water Gulf of Mexico (GOM), and the other in onshore unconventional shale resources.  In both scenarios the capital expenditure over the lifecycle of the investments amounts to approximately US$1 billion.  While the onshore project outperforms the deep water GOM at higher prices, below about US$80 per barrel and the deep water GOM is the more attractive unit it becomes marginal or uneconomic below about US$60 per barrel.

Figure 2 - Illustrative pre-tax rate of return - Deepwater GOM and Offshore Unconventional

A further key difference is the manner in which capital investments are made.  In the case of the GOM project, much or all of the US$1 billion capital is going to be committed and spent perhaps 5 years before any cash starts flowing back.  What is critical then is not the price of oil in 2015, but the price of oil in 2020.  From a decision-making perspective, that means the expected price of oil in 2020 and the risk that it may be something different when 2020 arrives.  Projects currently underway are unlikely to be stopped.  Exploration in 2015 is the 2018-2020 investment project, and halting exploration prematurely may mean not having the next project to take advantage of a stronger price environment at a later time.

In the case of onshore unconventional shale investment, decisions can be much more short term.  Drilling can be cut back, or ramped up, in fairly short order.  As shown in Figure 3, the US$1 billion of capital may in fact be only US$100-200 million of exposure, depending on the drilling intensity being undertaken, and this can be adjusted to accelerate or decelerate as market and corporate circumstances dictate.

Figure 3 - Cumulative project cashflow - Deepwater GOM and Onshore Unconventional

The data would therefore suggest that it is possible for good deep water GOM projects to be viable above US$60 per barrel, which suggests that for the medium term, even if prices were to stay around current (mid December 2014) levels there is sufficient incentive for ongoing activity without the benefits likely to accrue through cost reduction initiatives.  However, the extent of longer term activity relative to that which has arisen following 3-4 years of generally US$100+ per barrel oil is still going to be affected by where future oil prices appear to be settling, and the extent to which the industry is able to address cost inflation that has arisen in that same time window.

The range of companies in the onshore unconventional and deep water is quite different.  Onshore has a huge mix of players from small independents to majors, and the former are going to be driven heavily by having to address their financing needs.  On the other hand, deep water GOM is the preserve of the large independents and majors for whom it is more an issue of capital allocation than financing.  Thus to preserve value for the future suggests that companies with both asset types in their portfolio onshore unconventional projects will be preferentially be deferred, where other factors do not prevail.  

The start of 2015 is therefore likely to be driven by a combination of caution and capital realities.  Both fundamental economics and the flexibility of U.S. unconventional development - relative to offshore operations – suggests that this will be the focus of cost reduction while activity within the Gulf of Mexico will be more heavily influenced by perceptions of the medium to long term oil prices and any changes in activity levels expected to lag behind those experienced in the unconventional shale and tight oil plays.  


Pain Likely in 2015, But Deep Water GOM Should Be Better Placed Than Unconventional

Bob George

Global General Manager -
Pain Likely in 2015, But Deep Water GOM Should Be Better Placed Than Unconventional

Neil Abdalla

Senior Professional, Geoscientist -
Pain Likely in 2015, But Deep Water GOM Should Be Better Placed Than Unconventional

Cecilia Jing Cui

Consultant, Petroleum Economist -

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