Wolf Resources is proud to announce the successful $8.5 MM dollar closing of Wolf Energy Partners II, LLC. The entity is a focused investment for the purpose of acquiring and owning oil and gas assets, including non-operated working interests, mineral interest, leases and royalties in properties primarily located in the core liquids-rich Denver-Julesburg Basin. Matt Ritter, Managing Member of Wolf Resources says, “We are excited about building relationships within the investment and operating communities by providing our partners the opportunity to invest in targeted, high return and high value upstream oil & gas projects. Our technical team has a proven track record of identifying and exploiting value adding oil and gas investments. We are extremely optimistic about our future and the value we can continually create for our investors.”
Colorado citizens have the powers of initiative, both Statutory and Constitutional. To get on the ballot for the November 2018 general election, proponents needed to collect 98,492 valid signatures. Two initiative petitions are pending in Colorado that deal with oil and gas operations in the state.
Proposed Initiative Petition 97 is a Statutory Amendment requiring new oil and gas wells to be 2,500 feet from any “occupied structure” and “vulnerable areas,” and would change Colorado Revised Statutes. An exemption is made for federal lands. Current setbacks require new oil and gas wells to be 500 feet from an occupied structure and 1,000 feet from a higher-occupancy building (schools and hospitals, etc.) The proponents of Initiative 97 claim to have submitted 171,000 total signatures, but the Colorado Secretary of State must review and validate the signatures before the initiative may be placed on the ballot for the November general election. The Secretary of State has 30 days to complete the review and signature-validation process. If placed on the ballot, it requires a majority vote in the November general election to become law. However, because Initiative Petition 97 is a Statutory Amendment, it may be changed or repealed by the Legislature.
Proposed Initiative Petition 108 is a Constitutional Amendment being championed by the Farm Bureau that seeks to amend the Colorado Constitution to mandate that private property owners like homeowners, businesses, farmers, and ranchers are entitled to just compensation from state or local governments taking their property. The initiative would provide that any action taken by state or local government that reduces fair market value of private property would give rise to claims for just compensation. The proponents of Initiative Petition 108 submitted more than 208,000 total signatures to the Secretary of State’s office and, as is the case with Initiative 97, the Secretary of State has 30 days to review and validate the signatures. Assuming that occurs, it will be on the ballot for the November general election. If it receives at least 55% of the vote, it will become law.
By Tina Casey | Clean Technica |
If at first you don’t succeed…form a coalition! Atlantic coast states have been pushing back against the idea of permitting offshore drilling for oil and natural gas, and now it looks like industry stakeholders are making a fresh run at the issue. The new push comes from a familiar face — the American Petroleum Institute — but it features an interesting new co-chair, so let’s take a closer look and see what’s going on.
More Offshore Drilling For The East Coast…Or Not |
In a nutshell, API’s new “Explore Offshore” dangles the prospect of more than 25,000 high-paying jobs and $230 million in annual state revenues from offshore oil and gas drilling.
That’s some small potatoes when you spread it out among all 14 US states on the Atlantic coast (including New Hampshire, which just has a toehold). For now, though, the effort is focused on five states where support is relatively strong: Virginia, North Carolina, South Carolina, Georgia, and Florida.
API claims that the coalition consists of “more than 100 community organizations, associations, businesses and local leaders.”
That sounds pretty impressive, but there are some serious state-level forces arrayed against offshore drilling in all five states.
Take Georgia, for example. When the Trump Administration announced plans for offshore oil and gas drilling last January, Georgia Governor Nathan Deal was among the many coastal governors casting a stinkeye on the whole idea. Here’s the Associated Press with the rundown:
Georgia Gov. Nathan Deal expressed skepticism about the Trump administration’s plan to allow offshore oil drilling along Georgia’s coast.
Local media outlets report that Deal said he would need to consider the effect on the state’s tourism industry before deciding whether or not to support the federal government’s plan.
Okay so that’s a little mild, but check out what State Senator Lester Jackson said in April:
…Legislators who are not familiar with our coast don’t understand the biggest economic driver in the state is tourism. Many flock to our beaches for tourism. And they don’t understand another large business is our fisheries. Anything that may jeopardize that industry may cripple the coast.”
…We will continue our crusade to protect our shore and our two largest industries. To say nothing of protecting the environment. We don’t want what happened to the coast of Louisiana, and in Alaska to ever happen to us.
Jackson was among several Georgia legislators pushing for a formal resolution opposing offshore drilling. The measure failed but he and his supporters have vowed to fight on.
You Plans? We Got Plans, Too!
Speaking of Georgia, tourism is the fifth-largest employer and a $60.8 billion industry in the state, with $3.1 billion in annual revenue.
The offshore drilling plan comes at an especially bad time for the state. Georgia is positioning itself as a global tourism destination. Earlier this year, it unveiled its new 2018 travel guide with plans to distribute 700,000 free copies.
Here’s Deal pitching the new guide with a shoutout to the state’s tourism industry:
…the industry provides job opportunities for more than 450,200 Georgians, accounting for approximately 10.6 percent of the state’s non-farm workforce.
As this industry continues to grow, this success reflects our state’s status as a world-class tourism destination and once again affirms that Georgia is on the minds of travelers around the globe.
All The Good News About Offshore Drilling
Georgia’s new guide encourages tourists to “enjoy authentic Georgia experiences,” which could include an excursion to an offshore drilling platform if API’s campaign succeeds.
The Explore Offshore campaign has a chairman for each of the five targeted states. Georgia Chairman (and Georgia Petroleum Council Director) Hunter Hopkins promises that “many of our communities across Georgia could reap the benefits from offshore energy development as it would generate new state revenues for public schools and infrastructure.”
Explore Offshore also promises that “the oil and natural gas industry could create over 4,000 new high-paying jobs in Georgia” by 2035, and that “offshore development could result in $270 million a year in private investment into Georgia.”
At risk though, is the $2.4 billion in economic activity related to coastal tourism, along with more than 20,000 jobs (including part time and seasonal).
Meanwhile, the Savannah Morning News (here’s that link again) notes that coastal leaders are not convinced. In addition to opposition from environmental advocates, there’s this:
Local governments including Tybee Island and Savannah have passed resolutions opposing drilling and the seismic testing required to explore for oil and gas. Atlanta passed one in February. Richmond Hill passed its version just last month at the urging of The Dolphin Project, among other backers.
Some Bipartisans Are Better Than Others
API is touting its bipartisan cred by tapping former Virginia Senator Jim Webb, a Democrat, to co-chair Explore Offshore on a national level.
If you caught that thing about “former,” you’re on to something. Bipartisan means one thing in the private sector and another thing in elected office, namely, you get a vote.
The voting kind of bipartisan effort is taking shape in the US House of Representatives, where the Virginia Daily Press reports this happened just yesterday:
McEachin [Rep. A. Donald McEachin], a Democrat from Henrico County, introduced a bipartisan bill Tuesday along with Rep. Walter B. Jones, a North Carolina Republican, that would amend the Outer Continental Shelf Lands Act to forbid issuing federal lease-sales “for the exploration, development or production of oil or gas on the Outer Continental Shelf in the Mid-Atlantic planning area.”
So far the bill includes Virginia, North Carolina, Maryland, and Delaware, so stay tuned to see if representatives from Georgia, South Carolina, and Florida decide to tag along.
The biggest problem for API is that there is another significant offshore, job-creating energy alternative today, that being offshore wind farms.
Despite the Trump Administration’s pro-coal rhetoric, the Department of Energy has been pitching wind farms for the Atlantic coast states like gangbusters.
The nation’s first offshore wind farm has become a new tourist attraction for its home state of Rhode Island, so aside from the clean power and spill-free operation, there’s another benefit.
CleanTechnica is reaching out to Rep. McEachin’s office for the bipartisan perspective on wind farms vs. drilling platforms, and we’re also interested to see how Mr. Webb reconciles his Navy experience with the Department of the Navy stand on climate change so stay tuned for that.
Wolf Resources, LLC is pleased to announce the appointment of Tim Krebs as Chief Financial Officer. Tim has more than 14 years of experience in the energy industry and will be responsible for financial, accounting, corporate development and treasury functions. His knowledge of the oil and gas industry combined with his experience in the capital markets will help Wolf’s new phase of growth. Prior to joining Wolf, Tim held positions at Caerus Oil and Gas, Clarkson Plateau Securities and Black Opal Equity.
Matt Ritter, Managing Member of Wolf stated “We are excited to have Tim join Wolf. Tim brings with him a proven track record of strategic executive leadership. He will play a key role in accelerating our efforts to disrupt the market and challenge the traditional ways of thinking about our core business.”
Wolf Resources, LLC is pleased to announce that Travis Low has been promoted to Chief Operating Officer. Travis has 15 years of Oil and Gas experience and has worked for various public and private companies which include PDC Energy (“PDCE”) and Samson Resources. His experience includes corporate finance, business development, strategic planning and land.
Travis will be working with the Leadership team to remove obstacles, oversee general business operations, ensure alignment with the company’s vision, and lead large-scale strategic initiatives.
“Travis brings extensive Oil and Gas, financial, operational, and strategic experience to the Wolf family. As Wolf is focused on growth through targeted investments in the E&P space, we believe the addition of Travis better positions Wolf to capitalize and execute on sound investment opportunities. Overall, we believe Travis will be a huge asset to the company as we enter our next phase of growth.” – Matt Ritter, Managing Member
Matthew V. Veazey | Rigzone Staff
A word starting with the letter “o” that’s been rare in oil and gas in recent years – “optimism” – seems to be a popular sentiment at the 2018 Offshore Technology Conference (OTC), which began Sunday in Houston. How might the offshore oil and gas industry summarize its relationship with U.S. federal regulators? An energy policy pro with the Consumer Energy Alliance (CEA) suggests a pair of “c” words.
“A more collaborative and cooperative approach between government and industry” marks the key legislative and regulatory trends that the U.S. offshore industry has witnessed since the 2017 OTC, Brent Greenfield, CEA’s vice president of policy, told Rigzone. In addition, he said the federal government is implementing a policy agenda that “recognizes the importance of American offshore energy to U.S. jobs, a robust economy, strengthened national security and environmental leadership.”
Greenfield said that he expects more harmonious government-industry ties to continue as both entities work to implement the Trump administration’s agenda to achieve and maintain “energy dominance.”
“Over the course of the next year, the federal government will continue its evaluation of the areas to keep in play for potential access from 2019 to 2024,” said Greenfield. “Given the long lead times associated with the development of offshore energy, and the abundant energy resources that are located offshore, the decisions made over the next year – including whether to provide opportunities for expanded access in places like the Atlantic, Gulf of Mexico and Alaska – will play a major role in determining the strength of the nation’s long-term energy security.”
Federal officials participating in a CEA-arranged panel discussion Monday also pointed out that pursuing these goals need not come at the expense of safe operations and good environmental stewardship.
“As Chairman of the Subcommittee on Energy and Mineral Resources, I understand the importance of protecting our environment while promoting safe and responsible development of energy resources,” said U.S. Rep. Paul Gosar, an Arizona Republican.
“The reality is that oil and gas plays a fundamental role in the economy of the United States and the entire world,” added U.S. Rep. Garret Graves, a Republican from Louisiana.
Scott Angelle, Director of the U.S. Interior Department’s Bureau of Safety and Environmental Enforcement (BSEE), noted that the safe offshore energy operations are important because the industry creates jobs and provides royalties.
“We can have both,” said Angelle, who emphasized an “s” word and an “e” word. “We are not an either-or nation. We can have robust production and do it in an environmentally friendly way. It starts with safety, safety, safety and environment, environment, environment.”
By Matthew DiLallo | The Motley Fool |
For years, the focus of the oil industry was on growing production no matter the cost. Drillers would spend everything that came in — and then some — to drill new wells. This approach had disastrous consequences because it ultimately drove oil supplies well past demand, causing prices to crash, which made it hard for oil companies to keep up with the debt they incurred to juice growth.
However, thanks to a small handful of oil companies led by EOG Resources (NYSE: EOG) and ConocoPhillips (NYSE: COP), those days of growing just to grow are long gone. That’s because they’ve disrupted the industry’s long-held way of thinking and have shifted the focus from increasing production to growing shareholder value. It’s an approach that’s now spreading like wildfire, making the oil sector a much more appealing option for investors.
Drilling for returns, not oil
Through the years, most oil companies drilled new wells to produce more oil and gas. While they wanted to earn a return on their investments, many drilled countless money-losing wells. In fact, Chesapeake Energy’s CEO admitted a few years ago that at one point, 54% of its wells lost money.
EOG Resources, however, has started disrupting this mindset by making it clear that it sees the production of oil as a byproduct of its aim of earning a lucrative return on the capital it invests in new wells. While the company always has focused on drilling for returns, it cemented that view in early 2016 when it unveiled its premium drilling inventory, which are locations that can earn a minimum 30% after-tax return at $40 oil. By setting the bar that high, the company would ensure that its wells still would make money, even if crude plunged below $30 a barrel. One of the many benefits of drilling high-return wells is that EOG can produce more oil for less money, enabling it to grow faster than most rivals.
EOG’s focus on drilling to earn premium returns has already started changing the way competitors operate. Encana (NYSE: ECA) was one of the first to latch on to the idea when it unveiled its premium-return inventory in late 2016 along with a new five-year growth plan. The only difference was that Encana set a lower-return hurdle of 35% after tax at $50 oil. Meanwhile, many other drillers have started focusing their attention on identifying their highest-return locations, even if they don’t use the premium label.
In some ways, Encana has taken EOG’s focus on returns even further since the company no longer draws attention to how much it can grow production. Instead, it highlights its ability to increase cash flow. That change happened last year when it unveiled an update to its five-year plan.
Instead of targeting a production growth rate, Encana pointed out that it could increase cash flow at a 25% compound annual rate through 2022. Further, it could deliver that robust growth rate while generating $1.5 billion in free cash at $50 oil. Several other drillers have followed its lead by highlighting how much they can increase cash flow instead of trumpeting production growth.
By Alison Sider and Christopher Alessi | Wall Street Journal |
Bullish data in September have lifted prices |
An oil refinery and tanks stand near the U.S.-Mexico border. Photo: John Moore/Getty Images |
U.S. oil prices returned to bull-market territory while the global benchmark hit a two-year high, as investors gained faith that OPEC will successfully shrink a global supply glut.
A drumbeat of bullish data in September, including the International Energy Agency’s upward revision to its demand outlook, has lifted prices. Investors have become more confident that the Organization of the Petroleum Exporting Countries will continue cutting production and that its efforts are helping bring oil’s supply and demand into balance.
“It looks as though the market started to get convinced that the rebalancing is actually happening,” Tamas Varga, an analyst at PVM Oil Associates Ltd. said in a note Monday.
U.S. crude futures settled Monday nearly 23% above this year’s low of $42.53 a barrel on June 21, marking the sixth bull market for crude in four years and the first since February. A bull market is typically defined as a gain of 20% or more from a recent trough, while a bear market is a decline of 20% or more from a recent peak.
West Texas Intermediate, the U.S. benchmark, rose $1.56, or 3.1%, to $52.22 a barrel on the New York Mercantile Exchange, its highest settlement since April.
Brent, the global benchmark rose $2.16, or 3.8% to $59.02 a barrel—its highest settlement since July 3, 2015 and its largest daily gain since December.
Iraqi Kurdistan’s independence referendum played a role in boosting prices Monday, analysts said. Prices rose after Turkish president Recep Tayyip Erdogan made a veiled threat to close the pipeline that allows Kurdish oil to reach the global market.
Oil tumbled into a bear market in June as market participants grew skeptical of OPEC’s ability to bolster oil prices. Traders and investors were also wary that any rise above $50 a barrel would only spur U.S. shale producers to start pumping out more crude.
But recently, investors have been encouraged by signs that shale activity is starting to level off and that stockpiles are falling around the world.
Global demand has also been strong. The IEA earlier this month raised its forecast for demand growth this year and now expects an increase of 1.6 million barrels a day.
In a sign that prices could continue to recover, Brent crude has shifted into a market structure in which future prices are lower than near-term prices—an indication that supplies are tight and it isn’t profitable to sock away more oil in storage.
U.S. oil has also rebounded as U.S. refineries come back online in the wake of Hurricane Harvey. Prices still remain well below the high of $54.45 a barrel they reached in February.
Some hedge funds and other speculative investors are clinging to bearish bets on U.S. crude. Earlier this year, their bullish bets outnumbered bearish ones by more than 11 to 1, data from the Commodity Futures Trading Commission show. That has shifted to less than 3 to 1, according to the most recent data.
“The short sellers haven’t capitulated yet,” said Donald Morton, senior vice president at Herbert J. Sims & Co., who oversees an energy trading desk. “Those bears who are entrenched remain entrenched—they’re not convinced this is over.”
OPEC’s continued cooperation is still far from assured. The group hasn’t committed to extending its production cuts past March of next year.
And U.S. producers are once again likely to lock in higher prices for their future output—something that has capped previous rallies and worked against OPEC’s efforts, said Michael Tran, director of energy strategy at RBC Capital Markets.
OPEC and 10 producers outside the cartel, including Russia, first agreed in late 2016 to cap their production at around 1.8 million barrels a day lower than peak October 2016 levels. The deal was extended in May through March 2018.
In recent weeks, a number of signatories to the deal have indicated a willingness to hold back production potentially through 2018.
The group is trying to restrain output from Nigeria and Libya, members that were initially left out of the deal because their oil industries were crippled by civil unrest that was expected to tamp down production there.
“Undeniably now, we’re really seeing the fruits of OPEC’s labor,” Mr. Tran said. “But the key question is how much further can you go? This has given producers a key point to hedge. That could be troublesome—we’ve seen this movie before.”
—Stephanie Yang and Benoit Faucon contributed to this article.
By Darryl Fears, Washington Post |
The White House is making a bid to overturn the Obama administration’s five-year plan forbidding oil and gas exploration in the Arctic and Atlantic oceans and will examine opportunities to drill almost anywhere off the U.S. coast.
Interior Department officials said Thursday that opening most of the outer continental shelf to leasing is part of President Trump’s strategy to make the United States a global leader in energy production, stimulate coastal activity and create thousands of jobs. But as onshore oil and natural gas production has surged from horizontal drilling, helping to lower the price of petroleum, interest in offshore drilling has fallen.
A barrel of petroleum sells for less than $45, and many oil companies balk at the massive investment in equipment needed to drill offshore when the price is lower than $85, analysts say.
Vincent DeVito, Interior’s counselor for energy policy, said a 45-day comment period will start Monday with a request for public comment in the Federal Register. DeVito said stakeholders such as state governors would be contacted for their input, as will the Department of Defense, which frowns on exploration near bases and areas where ships conduct training exercises.
Royal Dutch Shell suspended drilling in the Arctic about two years ago when its oil exploration there produced a dry hole. The company said the result didn’t justify the massive risks and expense of drilling in the environmentally sensitive Arctic frontier.
DeVito said the Obama administration’s plan, to keep more than 90 percent of the outer continental shelf off limits, isn’t feasible given a recent Trump administration analysis showing oil production there could create 300,000 jobs.
“Our country has a massive energy economy, and we should absolutely wear it on our sleeves, rather than keep energy resources in the ground,” he said in a statement. “This work will encourage responsible energy exploration and production, in order to advance the United States’ position as a global energy force and foster security for the benefit of the American citizenry.”
On his way out of office in January, President Barack Obama banned offshore drilling in both ocean areas, removing regions that he said are “simply not right to lease.”
By Jennifer A Dlouhy, Bloomberg |
Donald Trump will tout surging U.S. exports of oil and natural gas during a week of events aimed at highlighting the country’s growing energy dominance.
The president also plans to emphasize that after decades of relying on foreign energy supplies, the U.S. is on the brink of becoming a net exporter of oil, gas, coal and other energy resources.
As with previous White House policy-themed weeks, such as a recent one focusing on infrastructure, the framing is designed to draw attention to Trump’s domestic priorities and away from more politically treacherous matters such as multiple investigations into Russian interference in the 2016 election.
With “Energy Week,” Trump is returning to familiar territory — and to the coal, oil, and gas industries on which he’s already lavished attention. Trump’s first major policy speech on the campaign trail, delivered in the oil drilling hotbed of North Dakota in 2016, focused on his plans for unleashing domestic energy production. The issue has also been a major focus during Trump’s first five months in office, as he set in motion the reversal of an array of Obama-era policies that discourage both the production and consumption of fossil fuels.
Plans for the week were described by senior White House officials speaking on condition of anonymity because the details hadn’t yet been formally announced.
Exports Equal Influence
Trump is set to deliver a speech at the Energy Department on Thursday focused almost entirely on energy exports — describing how the foreign sale of U.S. natural gas, oil and coal helps strengthen the country’s influence globally, bolster international alliances, and help stabilize global markets. Energy Secretary Rick Perry may touch on similar themes when he speaks Tuesday with analysts and executives at the U.S. Energy Information Administration conference in Washington.
“The fact that we’re no longer in the age of energy scarcity — that we’re in the age of energy abundance — positions the United States in a totally different place,” said Dave Banks, a special assistant to the president for international energy. “This gives access to affordable, reliable energy in the United States, and gives the U.S. a major competitive advantage.”
The focus on exports dovetails with Trump’s policy priorities, including improving the balance of trade, rebuilding heavy manufacturing and modernizing infrastructure, said Benjamin Salisbury, a senior energy and natural resources analyst with FBR & Co. The Trump administration seems to appreciate the synergy between extractive industries and manufacturing, Salisbury said, with cheap energy powering factories that are in turn churning out the equipment used to produce and export those resources.
Crude Ban Lifted
With U.S. oil production booming, former President Barack Obama signed a law lifting a decades-old ban on most crude exports in December 2015. Since then, the U.S. has exported more than 157 million barrels of crude to countries other than Canada, which had been exempted from the export ban.
The federal government has also authorized 21 billion cubic feet a day of natural gas to be liquefied and sent to countries that don’t have free trade agreements with the U.S. Since starting up last year, Cheniere Energy Inc.’s Sabine Pass terminal in Louisiana — the first major facility sending shale gas overseas — has shipped more than 100 cargoes of LNG to countries including Mexico, China and Turkey.
Trump is set to talk about opportunities for growth, including in sales of coal to Europe and Asia. A recent increase in the production of metallurgical coal used in steel manufacturing has helped East Coast terminals ship more of the resource overseas.
Wind, Solar, Nuclear
And the president is expected to describe openings for other energy exports, including U.S. technology that harnesses power from the wind and sun, and a new generation of advanced and modular nuclear reactors. Some nuclear power advocates have argued that the U.S. government process of licensing advanced reactor designs is so lengthy that it discourages investment.
The administration could go further to expand opportunities for using U.S. energy abroad by seeking to undo an Obama-era ban on the Export-Import Bank financing coal plants overseas. That could have special political resonance with coal miners who helped propel Trump to victory with wins in Pennsylvania, West Virginia and other states that have seen jobs tied to the fossil fuel decline.
The Trump administration has begun reversing a slew of regulations and policies that have limited energy development or made it more expensive, such as by ending a moratorium blocking new coal leases on federal land, and overturning a rule governing coal mining pollution in streams.
The president has ordered agencies to remove regulatory barriers to producing domestic energy resources, kicking off a broad government-wide review. Even as that analysis continues, the Interior Department has begun repeals or revisions of Obama-era mandates governing hydraulic fracturing and discouraging methane leaks from oil wells. A White House office is also vetting a proposal to repeal the Clean Power Plan, the Obama administration rule forcing states to slash greenhouse gas emissions from electricity production. And the Trump administration is considering more auctions of oil and gas leases in the Arctic and Atlantic oceans.
“It’s about utilizing our abundance of resources at home to create jobs and grow the economy, and at the same time use those to strengthen America’s leadership and influence abroad,” said Michael Catanzaro, a special assistant to the president on domestic energy.
Ironically, some of Trump’s policies could exacerbate the market challenges facing oil, gas and coal, by spurring more domestic production at a time when a supply glut is already suppressing prices.
The U.S. is on track to produce 10 million barrels of oil per day on average next year, according to a forecast from the Energy Information Administration — a milestone that would shatter a record set in 1970.
Trump’s theme of “energy dominance” marks an evolution. For years, the catch phrase of choice has been “energy independence,” as politicians and industry officials sought to highlight how a new era of abundance was helping the U.S. wean itself from foreign sources of oil and natural gas.
That was in turn a dramatic change from the 1970s, when former President Jimmy Carter turned down the White House thermostats and used a televised address in February 1977 to urge consumers to conserve energy amid a permanent “shortage.” After that, federal energy policy became rooted in the view that oil and gas were in short supply.
“Trump is reorienting our national rhetoric toward ‘dominance,’” said Kevin Book, analyst with ClearView Energy Partners LLC. “Captives crave independence; competitors strive to dominate. It’s a shift from getting by to getting ahead.”
By Oil & Gas 360, Oil & Gas 360 |
North Dakota adds most rigs
U.S. drilling activity continues to ramp up, stretching the rig rally to 22 weeks, according to Baker Hughes’ Weekly Rig Count.
Six additional rigs came online this week, bringing the total number of rigs active in the U.S. to 933. All six of these rigs were land-based, meaning there are now 908 land rigs operating in the country. Inland waters and offshore rigs saw no change, remaining at 3 and 22, respectively.
Oil-targeting rigs continue to increase their share of rig activity, adding six this week. One gas-targeting rig became active this week, while the lone “miscellaneous” rig shut down. In total, there are 747 oil-targeting rigs operating in the U.S., compared to only 186 gas-targeting rigs.
Surprisingly, horizontal rigs did not see the largest increase over the week. Instead, directional rigs grew the most, adding three this week. Two horizontal rigs came online and even vertical rigs saw growth, adding one. Horizontal well trajectories dominate American drilling activity even more than oil-targets do. This week’s count indicates a total of 782, 82 and 69 horizontal, vertical and directional rigs, respectively.
Rigs shifted around a great deal this week, and many of the major states that Baker tracks saw changes in active rigs. North Dakota saw the largest increase, adding three to end the week with 49 operational rigs. This is the largest change in North Dakotan rigs since March, when the state added five rigs. New Mexico, Alaska and Colorado each added two rigs this week, while California and Louisiana added one rig each. Oklahoma and Wyoming were the only states to lose rigs, with four and one rigs coming offline, respectively.
Permian, Eagle Ford stable
Unlike the major states, the major basins Baker tracks individually saw small changes. The Williston added three rigs, ending the week with 49 active. The Haynesville, Mississippian, Barnett and Cana Woodford all saw one rig come offline over the last week. None of the other major basins saw any change, including the Permian and Eagle Ford, where activity has been booming over the past few months.
By The Denver Post, PressReader |
The number of rigs exploring for oil and natural gas in the U.S. rose by six this week to 933. A year ago, just 424 rigs were active.
Baker Hughes said Friday that 747 rigs sought oil and 186 explored for natural gas this week. North Dakota added three rigs while Alaska, Colorado and New Mexico gained two rigs each. California and Louisiana increased by one. Oklahoma declined by four rigs and Wyoming was down one.
By Cathy Proctor, Denver Business Journal |
Anadarko Petroleum Corp., one of Colorado’s biggest oil and gas companies, on Tuesday said it would pour about $840 million this year into its operations in the state’s Denver-Julesburg (DJ) Basin, which sprawls north and east of Denver to the state line.
The company (NYSE: APC), which has been working in the DJ basin for years, also boosted the amount of oil, natural gas and liquids it expects to pull from the basin by about 33 percent — to more than 2 billion barrels of oil equivalent, at least.
As part of its annual announcement about capital investment for the year, Anadarko, based in a Houston suburb, said it believes there is still “additional upside on its acreage in the greater DJ Basin.”
Oil and gas companies have been increasing their activity and spending in recent months as crude oil commodity prices have hovered around $50 per barrel and the number of drilling rigs working in the field has started to rise.
Some analysts say those are signs that the industry is starting to recover from the massive, two-year downturn in commodity prices that savaged the industry, as companies responded by slashing budgeting, idling drilling rigs and eliminating thousands of jobs across the country.
But while companies appear willing to raise their budgets, the numbers are not anywhere near the size of their investments a few years ago.
Anadarko said it expects to operate an average of “five to six” drilling rigs and drill about 290 new oil and gas wells in Colorado this year. That’s a major jump from one rig the company operated in Colorado during 2016.
Anadarko in 2016 budgeted approximately $500 million in the Colorado’s DJ Basin. That was down from its 2015 budget, when it budgeted $1.8 billion — about $1 billion more than the company plans to spend in the basin this year.
The company is bullish on what it can do in the basin, saying in its presentation slides that it has scouted 4,100 locations for new oil and gas wells in the DJ and expects to double its production levels in the state by 2021.
Al Walker, Anadarko’s chairman, president and CEO, said in a statement the company expects to hit a new production benchmark in Colorado of 100,000 barrels per day during 2017, a 30 percent jump over 2016.
Overall Anadarko said its 2017 capital program is expected to be $4.5 billion to $4.7 billion, of which about 80 percent will be spent in the U.S. or in the Gulf. About $1.9 billion is earmarked for U.S. onshore operations, such as those in Colorado and Texas.
The overall budget is up 61 percent from the $2.8 billion the company spent in 2016.
In the U.S., the money will be focused on areas that Walker has called “the three D’s,” the Delaware Basin in Texas, the DJ Basin in Colorado and the deepwater Gulf of Mexico.
“In 2017, we plan to allocate approximately 80 percent of our total capital program toward our U.S. onshore upstream and midstream activities, and our expanded position in the deepwater Gulf of Mexico,” Walker said in a statement.
The spending plan not only gives the company a base to grow over the next five years, but the budget can be adjusted upward in Texas and Colorado if markets improve, he said.
“These investments provide the foundation for our increased five-year oil growth expectations of more than 15 percent on a compounded annual basis at current prices, and we are prepared to be flexible throughout the year if we see the opportunity in the Delaware and DJ basins to accelerate activity to capture additional value,” Walker said.
By Angie Haflich, High Plains Public Radio |
Like other High Plains states, Colorado’s oil and gas economy is in a position to help propel it forward.
As The Denver Post reports, oil prices rose after recent OPEC production cuts and are now high enough to motivate producers to put more rigs to work and translate into more domestic production, said Erica Bowman, chief economist with the American Petroleum Institute.
Colorado has 26 drilling rigs running in the state, compared to a low of 15 rigs working in May and the 76 operating in fall 2014.
While that may seem like a big gap, today’s rigs are much more productive than those operating years ago, according to EnerCom, a Denver-based energy consultant.
The Permian Basin of southwest Texas is an example, as rigs there are pulling up 3.4 times what rigs in 2014 did, EnerCom estimates.
More rigs and more drilling should translate into more hiring. But petroleum firms will face a much tighter labor market than was the case in 2012 and 2013, especially in Weld County, Colorado, the epicenter of drilling activity in the state.
Weld County’s unemployment rate in December was 2.6 percent, the lowest since 2000, according to the U.S. Bureau of Labor Statistics, in contrast to the 8.7 percent unemployment rate at the beginning of 2013.
If those firms do start to make a big hiring push, they will likely pull workers from construction and manufacturing, creating disruptions in those industries but there is also a sense that many firms took a hit to the bottom line and retained workers so they could be ready for a recovery.
A lot of things could cause the oil and gas recovery to fail.
One issue producers are watching closely are trade relations under the Trump administration, particularly changes to the North American Free Trade Agreement with Mexico and Canada.
Another trend to watch is how utilities respond to higher natural gas prices and whether they switch back to coal as a fuel source for electricity generation.
U.S. coal production last year suffered an 18 percent decline, reaching its lowest levels since 1978, according to the Energy Information Administration, which predicts coal production will rise 3 percent this year on higher demand from power plants. Colorado, despite adding large amounts of renewable energy generation, remains highly dependent on coal as a power source.
By Reuters, CNBC |
Brent crude slipped toward $56 barrel on Monday as a stronger dollar and ample U.S. supplies outweighed OPEC output curbs and rising tensions between the United States and Iran.
Brent crude was trading down 64 cents, or 1.1 percent, at $56.54 a barrel by 11:10 a.m. (1410 GMT). U.S. crude fell 45 cents, or 0.8 percent, to $53.38.
The dollar rose 0.2 percent versus a basket of currencies.
“It’s most likely the stronger U.S. dollar,” said Commerzbank analyst Carsten Fritsch of the reason for the dip in oil. A stronger dollar makes crude more expensive for other currency holders and usually weighs on the oil market.
Oil prices, while supported by supply cuts agreed by the Organization of the Petroleum Exporting Countries and a new spike in tension between Iran and the United States, are struggling for new direction.
“The tug-of-war between oil bulls and bears continued last week and there are no clear signs who could turn out to be the winner,” said Tamas Varga of oil broker PVM.
“The result is a rangebound market where buyers shy away on a pop over $57 basis Brent, but they feel a dip to the $54 level is an attractive purchase.”
The Trump administration’s new sanctions against Iran, though not affecting oil output, raised concern about the potential for further developments that could hinder export growth in OPEC’s third-largest producer.
Tension between Tehran and Washington has risen since an Iranian missile test that prompted the United States to impose sanctions on individuals and entities linked to the Revolutionary Guards.
“The growing tensions between the U.S. and Iran are …having a price-supportive effect,” Commerzbank said, adding that, while the sanctions don’t affect output, “this could change if the situation were to escalate”.
Iran has been raising crude output since most international sanctions over its nuclear programme were lifted in 2016. Tehran is exempt from the OPEC supply cuts.
The OPEC members covered by the deal with Russia and other independent producers have implemented at least 80 percent so far, according to a Reuters survey and analysts. Russia has cut about 100,000 bpd and plans to increase that to 300,000 bpd.
Implementation of the cuts began on Jan. 1 with the aim of reducing output by almost 1.8 million barrels per day.
Against this backdrop, more investors are betting on rising prices despite indicators such as the Baker Hughes rig count pointing to increased U.S. supply.
U.S. energy companies added oil rigs for a 13th week in 14, data showed on Friday. Despite the OPEC cuts, U.S. crude inventories rose by more than expected last week.
Investors raised their net long U.S. crude futures and options positions in the week to Jan. 31, the Commodity Futures Trading Commission said on Friday.
By Cathy Proctor, Denver Business Journal |
Higher prices for crude oil, natural gas and gasoline are among the highlights from the federal Energy Information Administration’s first short-term outlook for 2017.
The new forecast projects that U.S. crude oil prices, which averaged $43 per barrel in 2016, will rise this year to an average of $52 per barrel and will add on another $3 per barrel in 2018, to an average of $55.
U.S. gasoline prices, which averaged $2.15 per gallon in 2016, are expected to increase to $2.31 per gallon in the first quarter, and average $2.38 per gallon for this year and $2.41 per gallon in 2018, the EIA said.
On the natural gas front, average prices in 2016 were $2.15 per thousand cubic feet and are expected to jump to an average of $3.55 per thousand cubic feet in 2017 and $3.73 per thousand cubic feet in 2018.
On the production side, U.S. oil production averaged 8.9 million barrels per day during 2016 and is expected to rise slightly to 9 million barrels per day in 2017 and climb to 9.3 million barrels per day in 2018, the report said.
The EIA said it expects the new oil supplies will come from the Gulf of Mexico and shale oil plays across the U.S., such as in Colorado’s Denver-Julesburg Basin.
Natural gas production is expected to drop in 2016 to an average of 72.4 billion cubic feet per day compared to 2015 when production numbers are made final. If that proves to be true, it would be the first drop in the nation’s natural gas production since 2005, the EIA said.
Production increases are expected this year and next, rising by an average of 1.4 billion cubic feet per day in 2017 and 2.8 billion cubic feet per day in 2018, the EIA said.
Also, natural gas edged out coal as the leading fuel for electricity generation during 2016, the EIA said.
The agency said it estimates natural gas provided 34 percent of the nation’s electricity in 2016 while coal provided 30 percent, “marking the first time that a fuel other than coal provided the largest share of electricity generation on an annual basis,” the report said.
By Ron Bousso, Reuters |
Oil and gas discoveries around the world dropped last year to their lowest since the 1940s after companies sharply cut back in their search for new resources amid falling oil prices.
The decline in discoveries means companies such as Exxon Mobil and Royal Dutch Shell will struggle to offset the natural depletion of existing fields, reinforcing forecasts of a supply shortage by the end of the decade.
Total oil and gas resources found in 2016 reached just more than 6 billion barrels of oil equivalent (boe), said Sona Mlada, senior analyst at Oslo-based consultancy Rystad Energy.
The numbers do not include North American shale resources which have been a key driver in supply growth in recent years.
Offshore liquid discoveries, where most major new fields have been found in recent decades, reached 2.3 billion boe last year, 90 percent below 2010 levels.
As a result, companies were able on average to replace only 10 percent of their oil and liquid gas reserves last year, compared with a reserve replacement ratio of 30 percent in 2013.
“The lack of discovered volumes in 2016 will not have an immediate impact on the global oil supply in the short-term, given the lead time it takes from the discovery to start-up of a field’s production,” Mlada said.
“However, these ‘missing’ discovered volumes in the current years could have an impact on the global supply some 10 years down the line – depending on the investment decisions of the exploration companies.”
Several significant discoveries were announced in recent weeks including Exxon’s find of 100-150 million boe offshore Guyana and Statoil’s 80 million boe discovery off Norway.
Global exploration spending dropped in 2016 to $40 billion and could drop further this year, consultancy WoodMackenzie said last month.
As a result, the number of exploration wells drilled dropped last year by 40 percent from levels seen in 2014 when oil prices began the sharp decline, according to Mlada.
Around 60 percent of resources discoveries made last year were gas, she added.
By Bruce Finley, The Denver Post |
Federal land managers’ rule aimed at reducing burn-off, venting and leaks by oil and gas companies that gain the right to operate on public lands took effect Tuesday after a federal judge rejected an industry challenge.
Oil and gas companies that obtain leases to extract oil and gas from federal public land now must take steps to control their emissions into the atmosphere.
For years, companies have disposed of methane gas they could not process by opening valves and venting it and by partially burning off or “flaring” gas because they did not put systems in place to capture the gas for sale or use it on-site. Bureau of Land Management data show that companies between 2009 and 2014 wasted enough gas to power 5.1 million homes for a year. They wasted gas on which they otherwise would have had to pay royalties to state, tribal and federal governments.
U.S. District Judge Scott Skavdahl in Wyoming on Monday rejected an industry effort to prevent the rule from taking effect. Skavdahl concluded it was within the authority of the BLM to set this rule, but his decision left open avenues for the oil and gas industry to continue to fight it. He has set an expedited hearing schedule to resolve the issue fully in the coming months.
Conservation groups joined BLM officials in defending the federal rule.
“We’re very pleased. This rule benefits taxpayers by generating more royalties, and it protects the environment by preventing the release of methane,” Earthjustice attorney Mike Freeman said. “It is in the public interest to make sure taxpayers get a fair return on oil and gas leases and to limit the release of methane that is a powerful greenhouse gas.”
Federal BLM officials issued the rule in November 2016 and industry leaders immediately challenged it seeking a preliminary injunction.
“It’s difficult to get a preliminary injunction, and while we’re disappointed the judge was not willing to stop the rule now, we feel that our chances are very good once the full merits of the case are heard,” Western Energy Alliance president Kathleen Sgamma said. “There were several statements in his ruling that show he’s extremely skeptical of BLM’s authority to regulate air quality. We’ll be driving those points forward in more detail in our brief due in March.”
The WEA and the Independent Petroleum Association of America filed the lawsuit seeking an injunction to block the rule on federal and tribal lands. Wyoming, Montana and North Dakota filed similar lawsuits, which were consolidated into the industry case.
Oil and gas companies in their push to prevent limits on venting, flaring and leaks argued that federal land managers’ action was an illegal “arbitrary and capricious” abuse of federal power. They also argued that the BLM is usurping power to regulate air pollution that Congress has given to the Environmental Protection Agency, in concert with state agencies that implement and enforce rules — not the BLM. They argue it is up to the EPA and states to set and enforce rules to limit pollution of the air on public lands.
The BLM rule encourages oil and gas companies to collect natural gas rather than vent, burn or leak it from out-of-date equipment — in line with established mandates to prevent waste. A phased implementation of the rule requires oil and gas producers to use available technologies and systems to reduce flaring by 50 percent at oil wells on public and tribal lands. Companies must periodically inspect their facilities for leaks and replace old equipment that releases large amounts of gas. The rule also limits venting from storage tanks and requires companies to use best practices to minimize leaks when removing liquids from wells.
Skavdahl in his 29-page decision wrote that, “at this point, the Court cannot conclude that the provisions of the Rule which overlap with EPA/state air quality regulations promulgated under CAA (Clean Air Act) authority lack a legitimate, independent waste prevention purpose or are otherwise so inconsistent with the CAA as to exceed BLM’s authority and usurp that of the EPA, states, and tribes.”
Last June, Judge Skavdahl ruled that the BLM lacks authority from Congress to regulate the oil and gas industry practice of hydraulic fracturing, or fracking. BLM officials have appealed that decision to the 10th Circuit Court of Appeals in Denver. Industry petitioners in that separate case are scheduled to present their arguments in March.
By Cathy Proctor, Denver Business Journal |
Things in the energy sector are looking up, according to a fourth quarter industry survey from the Federal Reserve Bank of Kansas City.
Executives surveyed between mid-December and the end of 2016 say activity is up, and their outlook for the future has improved, according to the survey results.
Click Here to Read More – Denver Business Journal
By Art Berman, Forbes |
An OPEC production cut offers oil producers hope for higher prices in 2017. But there is a dark cloud hanging over that expectation. Global storage inventories must be substantially reduced before higher oil prices can be sustained. Some of U.S. tight oil has nowhere to go but into storage because it can neither be refined nor exported.
If all OPEC cuts take place as announced, it will be at least a year before sufficient inventory reductions allow prices to move much higher than current levels. If not, lower oil prices will last even longer.
The OPEC Production Cut and Spare Capacity
OPEC agreed to cut production in November partly because it was incapable of sustaining output at 2016 levels. Announcing a cut is a good way to cover the reality that commercial reserve limits have been reached.
Analyst narratives have created the unfounded but widely accepted belief that OPEC has a strategy, and that strategy involves a price war with U.S. tight oil producers. The cartel’s inaction since 2014 more probably reflected an unwillingness to repeat the mistake of cutting output between 1980 and 1985: those cuts had little effect on world over-supply and damaged OPEC market share and revenue.
The possibility of a production freeze was suggested in February 2016 when oil prices were less than $30 per barrel. Expectation of OPEC action and improving fundamentals lifted prices to an average of $43 per barrel in 2016.
Failure to act in November probably would have sent prices into the mid-$30 range. As my colleague Allen Brooks remarked just after the cut was announced, this is more about setting an oil-price floor than about raising prices.
By July 2016, OPEC surplus production capacity had fallen to only 0.92 mmb/d (million barrels per day). The all-time low was 0.71 mmb/d in late 2004 (Figure 1).
The negative correlation between oil price and OPEC spare capacity is obvious. Low OPEC surplus after 2004 along with increased demand from China corresponded to rising oil prices that reached $146 per barrel in June 2008. The exception to the correlation in late 2006 resulted from demand destruction when real oil prices (2016 dollars) exceeded $85 per barrel for the first time since 1982.
A production cut may bring higher short-term prices but it should also result in higher OPEC spare capacity, a negative factor for higher prices.
Massive Oil Inventories Are The Problem
After the 2008 Financial Collapse, declining OPEC spare capacity, falling OECD inventories, low-interest rates, and record-high oil prices produced a classic oil-production bubble.
The bubble burst in 2014 as over-production resulted in swelling inventories (Figure 2).
There is little chance that oil prices will return to the $70-80 range that many analysts predict until OECD storage falls approximately 400 million barrels to its 5-year average. If all the announced output cuts take place and extend beyond the 6-month term of the agreement, that will take at least a year.
The idea that there was a price war between OPEC and tight oil producers arose largely from a story line that analysts promoted. It was accepted and maintained largely by American hubris.
An over-supply of oil was the enemy if there was one and it negatively affected OPEC as much as other world producers. It resulted from the longest period of high oil prices in history. Brent was more than $90 per barrel from October 2010 through October 2014.
It is true that tight oil over-production was the biggest single offender in the supply glut and price collapse but all global producers contributed their share. It is likely that OPEC would have cut production in late 2014 if Russia had agreed to participate.
Ali Al-Naimi, the Saudi oil minister at that time said, “We met with non-OPEC producers, we asked ‘what are you going to do?’ They said nothing. We said the meeting is over.”
Tight Oil Is Not A Threat To OPEC
Tight oil has never been a long-term threat to OPEC because the reserves are relatively low. EIA year-end 2015 data indicates that U.S. tight oil proven reserves are less than 12 billion barrels.
Canada’s and Venezuela’s combined oil sands reserves exceed 350 billion barrels. Oil sands are Saudi Arabia’s and OPEC’s chief reserve competition, not U.S. tight oil (Figure 3).
In fact, tight oil production is a plus for OPEC. The U.S. must import increasing amounts of OPEC heavier oil for blending in order to refine the ultra-light oil produced from tight oil plays.
OPEC’S share of U.S. imports has increased 9% since January 2015. Total U.S. crude oil imports have increased about 1 million barrels per day and most of the increase has come from OPEC countries (Figure 4).
Canada could provide almost unlimited amounts of heavy oil to the U.S. but the Obama Administration’s decision to block the Keystone XL Pipeline means increasing reliance on OPEC.
Another Year of Lower Oil Prices
OPEC members leaked the possibility of a production freeze in early 2016 when oil prices were $26 per barrel. Fears of further price collapse began to fade reinforced by improving fundamentals.
The U.S. horizontal rig count fell almost 250 rigs (44%) between the end of 2015 and late May 2016. The world production surplus peaked in January 2016 and moved unevenly toward market balance throughout 2016 (Figure 5).
Oil prices rose to more than $50 per barrel by June but prices fell below $40 in August when an OPEC meeting in Doha failed to produce a production freeze agreement (Figure 6). Increased global output, slowing demand growth and higher petroleum products inventories also weighed on prices.
In late September, OPEC abandoned its market-based approach begun in 2014 and agreed to cut production. Prices moved up and down as the likelihood of a production cut waxed and waned through October and November. A deal was announced on November 30 and prices have increased from $43 to $54 per barrel mostly on sentiment.Without participation by Russia, there probably would have been no agreement to cut production.
It is clear that like the global economy, the oil-price recovery has been weak and fragile. Hope for some OPEC action has been a significant support for prices throughout 2016. There is probably $10 to $15 of “expectation premium” built into current oil prices.
Some analysts forecast $70 oil prices in 2017. I won’t recite the litany of reasons why OPEC members may cheat or that Libya and Nigeria may increase production. I am focused on the U.S. horizontal tight oil rig count that has increased 34% (85 rigs) since mid-September, 65% of which are in the Permian basin.
If two years of low oil prices have taught us anything it is that shale companies will produce oil at almost any price provided that investors give them money to drill. There does not seem to be any limit to investors’ willingness to believe that tight oil is a good bet.
There never was an over-riding strategy behind OPEC’s unwillingness to cut output over the last 2 years. More probably, it was based on a pragmatic recognition that cutting production without participation by Russia would not meet the cartel’s needs. Now that surplus capacity is exhausted and Russia has agreed to participate, a production cut makes sense.
U.S. output will rise but imports of heavier oil will be needed for blending. Excess tight oil will go into storage keeping U.S. inventories high and U.S. crude prices at a discount to Brent. OPEC will sell heavier oil to the U.S. at higher international prices. OPEC knows this but those who are celebrating what they believe is OPEC’s surrender in a make-believe price war, apparently do not.
Art Berman Petroleum Geologist and Professional Speaker Visit my website for more information: artberman.com