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Last Updated: December 13, 2017
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Adrin Shafil is a Drilling and Completions Manager for Petrofac, and is also a contributing writer for NrgEdge. He has a passion for ERD and is always thinking of the next breakthrough idea for the oil and gas industry.


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1. Before joining the oil & gas industry, you wanted to work in Silicon Valley, also known as the world-leading tech hub. What was the reason for the career move to oil & gas in Malaysia?

Actually, let’s talk about my previous aspirations, even before my ambitions for Silicon Valley. Since as long as I can remember, I wanted to be a doctor in my teenage years. The practice of medicine excited me, and I was an avid viewer of medical TV dramas such as E.R. Even at the end of high school, when ExxonMobil came knocking on my door during my senior year, I declined a scholarship with them in hopes of pursuing a career in medicine. However, ExxonMobil did not give up. After my exams, they invited me over to East Coast Malaysia, to visit their offices, a trip offshore and their processing plant. This was when I realized that I could achieve so much as an engineer, when I observed the complexity of the machinery and people on site hard at work. So, I took the engineering scholarship, and went to New York.


Fortunately for me though, ExxonMobil did not dictate which field I could sign up for. So, after taking a few introductory engineering classes, I finally chose Electrical Engineering, majoring in Computer Hardware design. So, my years at school were basically filled with tinkering with microprocessor design and assembly language (even more basic than computer science programming).
And yes, my ambition back then was slightly swayed by the allure of Silicon Valley, where I went to a few interviews with Intel, EMC2 and Microsoft, but after some soul searching, I decided to go back to my love for oil and gas, so I decided to join ExxonMobil in Kerteh, and was assigned to be part of the drilling team, and have remained a driller ever since.

2. Other than being a member of SPE, what are your other involvements outside of work and how do you find time to be involved?

I am fairly active with IADC (International Association of Drilling Contractors) as a speaker and committee member, as well as participating in industry technical committees led by PETRONAS. Recently I’ve been appointed as the Vice Chairman for WeDSTeC Committee by MPM Drilling in Petronas, which was a great honour. The WeDSTeC Committee is a drilling technical arm under the main umbrella of PETRONAS CORAL 2.0 industry-wide transformation programme, which stands for Cost Reduction Alliance 2.0.


And of course, my current online activities as a leadership influencer on LinkedIn and NrdEdge have proven to be quite rewarding, where I assist multiple layers of people in the oil and gas and other industries reach their true potential.


All of this are quite time-consuming, but I feel it is my responsibility to give back to the industry and community I live in, so I don’t let the time crunch bother me too much.

3. You graduated in computer and electrical engineering from Cornell University. How important is education in shaping one’s career path?

I believe that in high school or in higher level institutions, we are not actually merely learning equations, systems, rules or previous discoveries. What we learn is to develop our own abilities based on the fundamentals and tools given to us, where we are able to take our own path and succeed.


Another way to think about it is, every 3-5 years, a new job type is created, especially in the world of engineering and technology and it’s almost impossible for anybody to be educated specifically for that future job, that does not exist yet. Even in oil and gas, I believe with automation in the 4th industrial revolution with robotics and internet of things, the traditional draw and calculate engineering type will be displaced by program designers and data scientists. So, the journey of self-improvement and change will never end in the world we live in, so why should we limit our options based on our education when we were 18 years old?

4. Do you think that fresh graduates today are well-equipped to navigate their way in their careers? What are the skills and traits that are important to sustain a long-term career in the oil & gas industry?

I believe fresh graduates need to look beyond what they have already done, and have a vision of the future, while figuring out their place in that future. With the ability to reinvent themselves and have the right tools always for that vision, they can enter any industry with confidence, and specifically for oil and gas, they will be the catalysts for the new direction that O&G needs to move towards to, to catch up with the level of sophistication that can be found elsewhere. For example, the world is moving towards big data analytics, automation and A.I., so it’s almost impossible to think that O&G will not transform in the same way. And how will O&G be after the 4th industrial revolution? I will not be around then to witness those changes but the current new graduates will, so they need to be prepared for that future.

5. What are your thoughts on the concept of work-life balance? Do you think that reaching the top of the tier in your career, means losing that balance?

My personal opinion is a balance is entirely up to the individual’s goals in life. You can be great at something, but it’s impossible to be great at everything. And this applies to work-life. If you achieve an equal split between the two, then if you are happy with that, go for it. However, if you want to achieve greatness in perhaps a top tier position like a CEO of a company, then you have to make a choice. For some people, they are comfortable with their choice and make work-life possible. And for some, they do not differentiate between work or life, as life is both work and family. To each their own.

6. You’ve given talks about extended-reach drilling (ERD) and have mentioned it a number of times in your articles – why are you so passionate about ERD and what are your hopes for ERD technology in the future?

ERD has just a special place in my heart. Just like how architects and construction engineers race to build the next record breaking skyscraper, the same affection is felt for ERD by drilling and completion engineers. ERD represents the epitome of what drilling and completions engineers can achieve with the tools that they have. Right now, the world record is up to 13km in length, and Malaysian record is about 6.5km. Of course, well lengths are all dependent on the basin you are drilling, and there is no point drilling further and further if the well is unable to achieve the business value, but it remains my dream to be able to push Malaysian ERD industry to deeper frontiers. My hope is that technology for ERD escapes the confines of drilling rig limitations by transforming the way the tool’s energy source is received and converted to mechanical energy. Currently, hydraulics, torque, and pull are all supplied from surface by the rig, which then limits the ability to drill further. In other words, the rig has to be more powerful but there is a limit and cost on upgrading rigs. But if we can imagine self-powered bottom hole assemblies (tools downhole used for drilling), with powerful hydraulic pumps, and automated navigation abilities and closed loop corrections, we can definitely see the 20km barrier no longer be a hurdle.

7. You have managed to gain quite a large network on your LinkedIn profile and you’re very active on it. How important has your professional network been in your career journey?

I feel blessed and grateful with the following that I currently have, and I personally would like to help and guide as much as I can, with nothing expected in return. However, the interactions that I have and visibility allowed by LinkedIn, helps to create a personal digital brand for myself. I am a firm believer that branding is as important to a company and as important to an individual’s success.


In the real business world, the way I dress, the way I communicate is my visual professional brand. Online, what I share, what I write and comment, will become permanent virtual content, which will become my digital image, my personal brand and my legacy. The benefits of an excellent digital brand include a wider audience recognition of my abilities, spanning within and beyond my own field of expertise. With proper exposure, possibilities may arise to allow me to discover new things or pursue whatever it is that I’m passionate about.

8. Do you have a role model that you look up to?

I’m sure I’d embarrass my boss if I mentioned him by name, so I won’t. But to me, he is my role model as he embodies the company’s values, inspires me to take action and he never tires from coaching me with the right guidance and nudges for me to succeed. He is truly a leader, not a boss, and I’m glad to be working with him.

9. I’m sure you have accomplished many things in your life. Can you share your most memorable achievement?

My latest challenge was being able to deliver two wells with a lean budget and on a fast track basis, in what we recognize as a difficult time for the industry. Even the best laid out strategies could not be executed without a great team. My team this year was able to work within the business constraints, and with best in class performance, delivered the two wells safely. It was no easy feat as this was considered one of the most complex wells in Petrofac to date! I’m proud of my team and what they have achieved.


10. Was there ever a moment in your career when you were frustrated to the point of giving up? How did you recover from it?

Okay now it is time to be frank. I am a rather ambitious person and have been since I was in grade school. When my teacher asked me what I was going to be in the future, at the young age of 11, I answered confidently, “A Menteri Besar” (State Governor). While I did not choose the life of a politician, I’ve continued to be goal-oriented all my life, so I aim higher and higher at every stage of my career. So, when I don’t achieve what I want, or being told its not currently in the pipeline, of course I get crushed. An example was back in 2007, in my sixth year as an engineer, I was promised the job of a US Engineering Supervisor after completing my stint in the worldwide planning group. When I was told I had to wait for another year, I threw a fit and quit my job with immediate effect. That was not my proudest moment, but it all worked out well in the end, as I had plenty of opportunities with other companies and I would not be where I am now, if I did not make that change. But as I mature in the industry, I realize that opportunities have to be earned and may not be at the time what we want. So, perseverance and the ability to reinvent myself is key, because sometimes the opportunities given may be something entirely new, but I have to be ready for it.

11. What is next in the pipeline for you? Do you have a project you’re working on or would like to embark on?

Currently we have plenty of wells at Petrofac to be drilled, and future developments, that will keep me busy.

12. Finally, what is the one piece of valuable advice you can give to oil & gas professionals who are about to step into the industry?

Be mindful that the current difficulty in the industry may be longer than expected, so what the industry really needs are people with creative and innovative minds, to be able to maintain safety, operational excellence and achieve business objectives even with a tight budget. So, use the tools that you have, the skills that you’ve learnt and be ready to suggest the next change for oil and gas, and prepare to work and make it a reality. There will always be somebody to listen and guide you, but you need to be able to drive yourself to achieve your goals.


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What Stays, What Goes

It was a headline that definitely opened eyes and definitely perked up ears. News that supermajor Shell was in the process of reviewing its holdings in the largest US oil field – the onshore Permian basin – came as a shock. On one hand, why was Shell looking to sell off its assets in the prized US shale patch only months after naming it one of its nine ‘core’ upstream areas? On the other hand, the prospect of taking over Shell’s sizable acreage in the Permian has set its competitors operating in the same shale patch sniffing around for opportunities.

The answer to the former has been most influenced by a recent judgement at a court in The Hague, where Royal Dutch Shell is headquartered. The court ruled that Shell’s carbon plans – which calls for a reduction of greenhouse gas emissions to net zero by 2050 and an absolute 20% reduction by 2030 – was insufficient and not in line with the climate change goals of the Paris Agreement. Instead, the court ordered that Shell must reduce its emissions by 45% from 2019 levels by 2030, siding with environmental NGO Friends of the Earth which brought on the case by claiming that Shell was violating human rights with its current plan. Crucially, and unusually, the court applied the verdict to Shell’s entire global operations, spanning multiple jurisdictions, rather than limited to just Dutch holdings. Shell has announced plans to appeal, which could drag the process on for years in higher courts. But on the off-chance that this judgement remains binding, it is perhaps looking for ways to shave off carbon-intensive assets.

Why else would chatter suddenly surface that Shell was considering selling off its collection of prime Permian acreage located in the prolific Delaware basin? After all, just a few months ago in February, Shell announced that it was planning to reshape its upstream business to focus on nine core areas that generated 80% of its revenue – Brazil, Brunei, the Gulf of Mexico, Kazakhstan, Malaysia, Nigeria, Oman, the UK North Sea and, of course, the Permian Basin in the US. Although Shell is not among the largest Permian players, its 260,000 acres are still sizable and its output of some 60,000 b/d ranks Shell among the Permian’s 20 largest producers. Valuations suggest that the sale could fetch as much as US$10 billion, which is a lot of cash that Shell could redirect to clean energy initiatives if the aim is to conform to the court order. Because Shell is not exactly in fire-sale mode; its asset divestment program to hive off non-core assets to pay for its US$53 billion acquisition of BG Group in 2015 was already complete.

To be fair, for all the activity in the Permian, sustained profitability has proven elusive. Not just to Shell, but other major players there as well. The rapid drop-off in well productivity after the first two years means that players have to be constantly drilling and discovering, while a large-scale traditional crude oil field could last for decades after initial production. Shell is also not the only one to consider shedding assets; Chevron and ExxonMobil are also rumoured to be considering divestment as well. And why not? With crude prices at their highest point since late 2018, it is a good time to fetch the best price for oil assets. Most Permian deals in 2021 have closed at between US$7,000 and US$12,000 per acre – already a major increase from 2020 and 2019 – but Shell’s prime 260,000 acres acquired from Chesapeake Energy and Anadarko in 2012 would fetch a major premium, possibly almost as high as US$40,000/acre that would be in line with Pioneer Natural Resources’ acquisition of DoublePoint Energy in April 2021. Any sale would definitely exceed Shell’s initial investment of US$1.9 billion, fetching a tidy profit. Of course, the move would also shrink Shell’s US footprint, limiting it to the Gulf of Mexico (where the Whale field FID is expected soon) and a single oil refinery (Norco), after selling its stake in the Deer Park refining site to Pemex from an unsolicited bid.

If the sale goes through – and it is still a big if at this point – then Shell’s loss will be someone else’s gain. Who would that be? Potential bidders include ConocoPhillips, Devon Energy, Chevron, EOG Resources or even private equity firms that have not been scared off by the potential debt burden of Permian assets. Shell is likely to be looking for an all-cash deal for the entirely of the asset, but is reportedly open to also parcelling up the land into multiple packages. According to sources, a data room with full information on the assets has already been opened.

Looking at the location of Shell’s Permian assets, synergies exist with ConocoPhiliips and Chevron, which both own acreage close to the Shell holdings. Other potential buyers that operate in the Delaware region of the Permian include Occidental and EOG, with Devon Energy being the smallest company that could likely afford a purchase. But Occidental is still busy adjusting after outbidding Chevron in a blockbuster acquisition of Anadarko, which could preclude a purchase by Shell’s partner in its Permian operations. Pioneer Natural Resources might also be excluded as a potential buyer, given that it primarily focuses on the Midland region east of Delaware. But even if the desire is there, there are additional hurdles. Given the immense focus on climate change and the industries that contribute to it, capital is increasingly a challenge, since the financing of fossil fuels is under massive pressure.

Not that those hurdles are insurmountable. The pressures facing a supermajor like Shell – or even ExxonMobil and Chevron – do not necessarily apply in the same measure to other players. If Shell is willing to sell, then there will be plenty of willing buyers vying for the assets. But what is also certain is that recent climate change moves that are ongoing in the boardrooms of energy giants are starting to have very concrete implications and applications on operations. The heat fuelling merger and acquisition activity in the Permian is about to get a lot hotter.

Market Outlook:

  • Crude price trading range: Brent – US$72-74/b, WTI – US$70-72/b
  • Both global crude benchmarks – Brent and WTI – cross the US$70/b threshold, recording the highest level of crude prices since October 2018, as the market focuses on the sustained improvements in fuel demand heading into the crucial summer season in the normal atmosphere that typically boosts road and air travel
  • The outbreak of new Covid variants is still a concern, but the accelerating pace of vaccinations – even in the hardest-hit countries– are providing some reassurance that any current lockdowns will not be prolonged
  • OPEC+ is predicting that oil demand growth will jump by 5 mmb/d in the 2H21 from 1H21 levels, setting the stage for further easing of the OPEC+ supply quotas; Iran’s return to international crude markets is likely to be further afield as talks to revive the 2015 nuclear deal enter into roadblocks

End of Article

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June, 19 2021
What’s Next For Canadian Oil Sands

It cannot be said that the conversation around sustainability and carbon intensity in the energy industry happened overnight, since the topic has been a subject for over five decades. But what has changed is that there has been a major acceleration in the discussion in the last year, and even the last month. The European majors and supermajors have all adopted ambitious carbon-neutral goals – even though some jurisdictions are saying that those aren’t even enough. Over the pond, even shareholders are pushing the traditionally more reticent American giants to adopting stronger climate change goals. Nothing is more emblematic of this change that the shareholder revolt at ExxonMobil’s recent AGM, where upstart activist investor Engine No. 1 managed to oust a quarter of ExxonMobil’s board; the initial tally saw two of its candidates elected, but the final numbers showed that three of Engine No. 1’s nominees now sit on the Board of Directors with a remit to initiate climate change manoeuvres from the inside.

That sort of conversation will be jittery for a particular section of the industry: Canadian oil sands – the heavy, sandy deposits of bitumen in Alberta that provide Canada with the third-largest proven oil reserves in the world. Extracting this heavy stuff is expensive, requiring large-scale excavation and massive capital spending that only really made economic sense with the oil price boom in the late 2000s. Shipping this tarry substance is also a challenge, necessitating dilution with lighter crudes to be shipped via pipeline – which is the only major viable route to market for landlocked Alberta, sending the tarry substance all the way south to the US Gulf Coast for processing. The problem is that extracting oil sands is extremely energy-intensive – with the main culprit being steam injection to liquify the underground bitumen – that has resulted in some of the highest carbon emissions per barrel in the world. In a world racing towards net zero carbon emissions, that is quickly proving to be unacceptable.

So while the climate change debate rages on in the boardrooms of the largest energy firms, the exit has already begun from Alberta, operationally and financially. The latest moves come from Chevron, which saw its shareholders overturn the company’s recommendation to instil stricter emissions targets for its crude, and the New York State Common Retirement Fund, the third-largest in the USA. Chevron’s CEO Mike Wirth recently signaled that he was open to offloading its 20% stake in the Athabasca oil sands project, stating that even though it generates ‘pretty good cash flow without needing much capital’ it was not a ‘strategic position’. Wirth insisted that Chevron wasn’t operating on a ‘fire-sale mentality’ but would consider selling if it got ‘fair value’ – with in business-speak is basically as invitation for offers. But would those offers be forthcoming? Investors all around the world have pulled back from financing Canadian oil sands, limiting the pool of potential buyers. In April, the New York state pension fund restricted investment in six oil sands companies – Imperial Oil, Canadian Natural Resources, MEG Energy Corp, Athabasca Oil Corp, Japan Petroleum Exploration and Cenovus Energy – claiming that they ‘do not have viable plans to adapt to the low-carbon future, posing significant risks for investors’. The amount of funds (US$7 million) is a drop in the ocean for the US$248 billion pension fund, but the message it sends is loud and clear.

Taken as it is, this could be an exit. But taken as a collective movement considering divestments over the past 3 years, this is an exodus. In May 2020, Norges Bank Investment Management – the world’s largest sovereign wealth fund with over US$1 trillion in assets gleaned from Norway’s oil industry – pulled back entirely from Canadian oil sands, selling nearly US$1 billion in four major firms citing concerns over carbon emissions. While no other major pension fund has followed suit, private investors have, including titan BlackRock that has begun to exclude oil sands from its major funds Financing is also proving tricky, with a string of major banks – including HSBC, ING and BNP Paribas – either paring back or stopping lending entirely to the industry; the insurance industry is also pulling back, with The Hartford stopping investing or insuring of the Alberta crude oil industry.

These high-profile investment and financing moves have dimmed the shimmer of an industry that was never that clean to begin with. But what will hurt is the pullback of upstream players, which hollows out the pool of companies left to exploit what is an increasingly unattractive asset. Before Chevron even contemplate its sale, Shell already sold its assets in 2017 for US$8.5 billion and ConocoPhillips offloaded to Cenovus Energy as part of a broader sale including gas assets for US$13.3 billion, also in 2017. Norway’s Equinor, too, has liquidated its position. Then in February 2021, ExxonMobil dropped a bombshell – effectively eliminating every drop of oil sands crude from its worldwide reserves, a tacit admission that oil sands would not form part of its upstream focus (at least at current prices) for the foreseeable future, especially with more attractive propositions in Guyana and the Permian. Given its recent shareholder revolt, it is unlikely that oil sands will be back on the menu ever.

The players in Alberta are trying to fight back. Having been consolidated in less than a dozen major players – from oil sands specialists to more integrated players such as Suncor – the industry is trying to rally institutional support, stating that traditional industry is still necessary to build the clean energy industries of the future. Suncor’s CEO Mark Little puts it this way: ‘this is way more complicated (than its seems)… the wind farm can’t be the solution to every problem. It’s not. So we need to find innovative solutions.” The oil sands patch’s biggest players are also banding together to form an alliance to achieve net-zero greenhouse gas emissions by 2050 – similar to the goals of most energy majors – as it tries to convince not just the world, but also Canada’s own government that Alberta has a continued role in the country’s energy transition. Efforts include linking facilities in Ford McMurray and Cold Lake to a carbon sequestration hub, expanding carbon capture and storage technology, accelerating clean hydrogen and other clean technologies such as direct air capture and fuel switching. The timeframe and viability of this is critical, given that Prime Minister Justin Trudeau has already announced plans to raise Canada’s carbon price steeply to accelerate its energy transition.

Those are bold plans and bold ambitions. But will it be enough? Can the exodus be stemmed? Or will the industry be whittled down to a handful of local players isolated from the wider energy world, removed from climate change engagement completely? It is difficult to tell at this point, but at the very least, things are starting to move in the right direction. Even if the pace is as slow as the crude sludge mined in Alberta.

End of article 

Market Outlook:

-       Crude price trading range: Brent – US$71-73/b, WTI – US$69-71/b

-       Confidence in the crude markets has vaulted global price benchmarks to their highest level in two years, with both Brent and WTI exceeding the US$70/b psychological level

-       Underpinning this rally are signs that vaccinations are boosting economic activity, with the likelihood of some travel and hospitality sectors reopening fully across the northern hemisphere’s summer, while crude marker indication show tightness in the market

-       That will reinforce OPEC+’s position to ease its supply quotas from July onwards, with club’s goal likely to be keeping prices around US$70/b – a level that should stabilise internal finances and budgets for most member countries. 

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June, 13 2021
M & A in the US Shale Patch

It is only 5 months into 2021, and already Bloomberg estimates that merger and acquisition (M&A) activity in the US shale patch has more than doubled over the equivalent period in 2020 to over US$10 billion. Given that Covid lockdowns sapped energy from shale drilling from March 2020 and what was left was decimated again in April 2020 when US WTI prices (briefly) collapsed into negative territory. From this point onwards, it may not take much to maintain this doubling of M&A activity in the US shale patch over the next 7 months. But don’t call this a new trend; call it what it is: the inexorable centralisation of US shale as the long freewheeling Wild West years give way to corporate consolidation.

Even before Covid had been unleashed upon an unsuspecting world, this consolidation was already in full swing. When the US shale revolution first began accelerating in the early 2010s – when crude oil prices were high and acreage was cheap – there were thousands, maybe even tens of thousands, of small independent drillers vying alongside medium and large upstreamers busy striking riches across American shale basins such as Bakken, Eagle Ford, Marcellus and, of course, the Permian. But too many cooks spoiled the soup. The US shale drillers who were acting capitalistically without concern for discipline incurred the wrath of OPEC and caused the oil price bust in 2014/2015. For larger players were deep pockets and wide portfolios, the shock could be absorbed. But for the small, single field or basin players, it was bankruptcy staring them in the face. The sharp natural productivity dropoff of shale fields after initial explosive output meant profits had to be made super quick and super fast; if debt kept mounting up, then drillers must keep pumping to merely stay alive. But there is another option: merge or acquire. And so those thousands of players started dwindling down to hundreds.

But it wasn’t enough. Even though crude prices began to recover from 2016, it never again reached the dizzying levels of the boom years. Debt accumulated turned into debt to be repaid. And the financial community got wiser. Instead of being blinded by the promise of shale volumes, investors and shareholders started demanding value and dividends. Easy capital was no longer available to a small shale driller. And because of that no new small shale drillers emerged. Instead, the big boys arrived. Because shale oil and gas still held vast potential, the likes of ExxonMobil, Shell and Chevron started moving in. ExxonMobil went as far as calling the Permian its ‘future’ (though this was in the days before its super discoveries in Guyana were announced). With consolidation came cohesion. Instead of a complicated patchwork of small plots, a US shale operator’s modus operandi was now to look to its left or right for land that someone else owned which could be stitched up into its own acreage forming a contiguous asset. And so those hundreds of players started becoming dozens.

In late 2020, this drive ratcheted up as the prolonged Covid-caused fuels depression freed up plenty of candidates for deep-pocketed players. ConocoPhillips bought Concho Resources for US$9.7 billion. Pioneer Natural Resources snapped up Parsley Energy for US$4.5 billion. Chevron closed its US$5 billion acquisition of Noble Energy (after failing to acquire Anadarko after being outbidded by Occidental Petroleum in 2019), while Devon Energy snapped up WPX Energy for US$2.56 billion. All four were driven by the same motive – to expand foothold and stitch up shale assets (particularly in the Permian). This series of M&As rejigged the power balance in the Permian, propelling the four buyers into the top eight producers in the basin, joining Occidental, EOG, ExxonMobil and Chevron. These top eight Permian producers now have output of over 250,000 b/d, accounting for nearly 60% of the basin’s 4.5 mmb/d output.

You would think that this trend would continue until the Permian Big Eight became the Permian Big Four for Five. And this could still happen. But the latest M&A activity from a major Permian player suggests that the ambition may well be too constrained. Cimarex Energy, the tenth largest player in the Permian with output of some 100,000 b/d, just entered into a merger to create a US$17 billion Houston-based shale driller. But its partner was not, say, fellow Permian buddy SM Energy (80,000 b/d) or Ovintiv (75,000 b/d). Instead, Cimarex chose Cabot Oil & Gas, a gas-focused player that operates almost entirely in the Marcellus shale basin in Appalachia, over 1500km away from the Permian.

In response to the merger, share prices of both Cimarex and Cabot fell. Analysts cited a dilution of each company’s core focus (along with the meagre premium) as concerns; implying that investors would be happier if Cimarex stayed and grew in the Permian, and Cabot did the same in Marcellus. But that’s a narrow way of thinking that both Cimarex and Cabot were happy to refute. “This is a long term move,” said Cimarex CEO Tom Jorden. “This combination allows us to be ready for those (swings in commodity prices)”.

While pursuing in-basin opportunities could make shareholders happy in the short-term, a multi-basin deal might be a surprise but is also a canny long-term move. After all, at some point the Permian will run out of oil. And so will gas in Marcellus. Or the US government could accelerate its move away from fossil fuels. If an energy company puts all of its eggs into one basket – or basin, in this case – then when the river runs dry, the company’s profits evaporate. It is a consideration that other single-basin focused players like Pioneer, EOG and Diamondback will need to start thinking about, which is a luxury that other integrated players with Chevron and ExxonMobil already have. Consolidation in American shale basins is inevitable. But what is far more interesting is the new potential of cross-basin consolidation.

Market Outlook:

  • Crude price trading range: Brent – US$67-69/b, WTI – US$64-66/b
  • Global crude oil prices remain locked in their current ranges, with bullish signs of fuels demand recovery in North America, Europe and China offset by signs that the Iranian nuclear deal could be revived, which would lead increase OPEC supply
  • Iran, if reports are accurate, has already been preparing for this, establishing contact with former clients to gauge interest and pave way for its re-entry to the global oil markets, which could swell OPEC production by nearly 4 mmb/d
  • This will be a point of contention within the OPEC+ supply deal framework, since Iran would argue for exemptions (as Russia, Kazakhstan and Libya have) from official quotas; although the latest rhetoric from Iran suggests there are still plenty of gaps to restore the original 2015 nuclear agreement, allaying fears of a quick ramp-up
June, 08 2021