Since days when shale oil and gas technologies were discovered, the U.S. energy industry has been evolving more rapidly than ever before. Many changes are amazing especially when you put them on an industry map. At Rextag not only do we keep you aware of major projects such as pipelines or LNG terminals placed in service. Even less significant news are still important to us, be it new wells drilled or processing plants put to regular maintenance.
Daily improvements often come unnoticed but you can still follow these together with us. Our main input is to “clip it” to the related map: map of crude oil refineries or that of natural gas compressor stations. Where do you get and follow your important industry news? Maybe you are subscribed to your favorite social media feeds or industry journals. Whatever your choice is, you are looking for the story. What happened? Who made it happen? WHY does this matter? (Remember, it is all about ‘What’s in It For Me’ (WIIFM) principle).
How Rextag blog helps? Here we are concerned with looking at things both CLOSELY and FROM A DISTANCE.
"Looking closely" means reflecting where exactly the object is located.
"From a distance" means helping you see a broader picture.
New power plant added in North-East? See exactly what kind of transmission lines approach it and where do they go. Are there other power plants around? GIS data do not come as a mere dot on a map. We collect so many additional data attributes: operator and owner records, physical parameters and production data. Sometimes you will be lucky to grab some specific area maps we share on our blog. Often, there is data behind it as well. Who are top midstream operators in Permian this year? What mileage falls to the share or Kinder Morgan in the San-Juan basin? Do you know? Do you want to know?
All right, then let us see WHERE things happen. Read this blog, capture the energy infrastructure mapped and stay aware with Rextag data!
The oil and gas industry has long relied on the recommendations of trusted experts to make key supply chain decisions. The growing popularity of Blockchain technology could significantly disrupt these relationships by providing an unbiased methodology for sourcing, tracking, and executing transactions on behalf of customers with transparent data sets across supply chain endpoints. Blockchain technology has already been used by many global companies in the last two years in various areas such as IoT (Internet of Things), smart contracts, and cryptocurrencies. It has enabled businesses to benefit from the inherent trust and transparency of the technology.
On January 5 Northern Oil & Gas (NOG) concluded a deal to acquire working interests in Midland-Petro D.C. Partners LLC (MPDC)'s Mascot Project in the Midland Basin, according to a January 9 press release. Firstly estimated at $330 million in cash, the deal was signed with an additional 3.25% working interest added to the 36.7% agreed upon when the transaction was announced on October 19. NOG paid $29 million more for the additional interests, which now totalled 39.958%. Finally, the deal closed for $320 million in cash and $43 million in debt at signing in October with the finance of Minnetonka, Minn.-based NOG with cash on hand, operating free cash flow, and assistance from its revolving credit facility.
Talos Energy Plans to Close the EnVen Acquisition Soon: Stockholders to vote on $1.1B Deal on February 8
Talos Energy Inc. is closing its $1.1 billion purchase of private operator EnVen Energy. A special meeting for Talos’ stockholders to vote on the deal and other matters is set on February 8, according to a prospectus filed on January 11 with the Securities and Exchange Commission. Shareholders are being asked to approve the EnVen merger, which as the company considered in September would raise its Gulf of Mexico production up to 40%. According to a January 11 press release, Talos asserted that it anticipates closing the transaction soon after the meeting. Talos Energy Inc. supposes that adding EnVen would double its operated deepwater facility footprint, extending key infrastructure in existing Talos operating areas. More than 80% of the combined assets will be deepwater, with the company operating more than 75% of the acreage it holds interests in. Talos is one of the largest independent operators in the U.S. Gulf of Mexico, with production operations, prospects, leases, and seismic databases spanning the basin in both Deep Water and Shallow Water. The company aims to actively grow through a balanced focus on asset optimization, development, and exploration while also seeking to add to its portfolio through acquisitions and business development.
On January 3, U.S. natural gas producer Rockcliff Energy from private equity firm Quantum Energy Partners was set to be sold to a unit of Tokyo Gas Co. Ltd. for roughly $4.6 billion, including debt. The all-cash agreement with Houston-based TG Natural Resources, which is 70% possessed by the Japanese energy firm, is decided to be claimed this month, according to anonymous resources, as the discussions were requested to be confidential. Castleton Commodities International (CCI) owns the rest of TG Natural Resources.
According to the company’s press release on December 19, Northern Oil and Gas Inc. (NOG) closed its announced deal with a private seller of non-operated interests in the Northern Delaware Basin for $131.6 million in cash. The acquisition was announced with a $13 million deposit in October and is the third Permian Basin acquisition since August, adding to NOG’s $400 million of Permian Basin acquisitions in 2022. The assets of 2,100 net acres are primarily operated by a private company Mewbourne Oil Co., with production anticipated to total almost 2,500 boe/d in 2023. Also, Coterra Energy Inc. and Permian Resource Corp. are operators of the assets. The assets contain high-quality, low breakeven development that is leveraged to some of NOG’s top operating partners, as our investors have come to expect.
Marathon Oil Corp. closes the acquisition of Ensign Natural Resources’ Eagle Ford assets for $3 billion cash, according to the company’s release on December 27. The purchase includes 130,000 net acres (99% operated, 97% working interest) in acreage adjacent to Marathon Oil’s existing Eagle Ford position. Ensign’s estimated fourth-quarter production will average 67,000 net boe/d, including 22,000 net bbl/d of oil.
On December 15, Pipeline giant Williams made a deal to purchase MountainWest Pipelines Holding Co. from Southwest Gas Holdings Inc. for almost $1.5 billion including debt. Williams is paying $1.07 billion in cash and assuming $0.43 billion of debt to buy MountainWest, which comprises approximately 2,000 miles of interstate natural gas pipeline systems mainly situated across Utah, Wyoming, and Colorado.
Northern Oil and Gas Inc. (NOG) made a $330 million purchase in the Permian Basin, according to the release on October 19. NOG revealed an agreement to purchase a 36.7% working interest in the Mascot Project from Midland-Petro D.C. Partners LLC (MDPC). The acquisition will be funded with cash on hand, operating free cash flow, and borrowings. The Mascot Project is operated by Permian Deep Rock Oil Co., an affiliate of MPDC, which is a David H. Arrington-owned business based in Midland, Texas. NOG anticipates that the production from the acquired properties to average almost 4,400 boe/d in the first quarter of 2023 and 6,450 boe/d for the full-year 2023 (2-stream, about 80% oil).
Talos Energy Inc. is acquiring EnVen Energy Corp. for $1.1 billion to raise Talos’ Gulf of Mexico production by 40%. The purchase of EnVen, a private operator, increases Talos' operated deepwater facility footprint 2 times, expanding key infrastructure in existing Talos operating areas. Almost 80% of the assets will be deepwater, with Talos operating more than 75% of the acreage it holds interests in. During a conference call on September 22, it was announced that the EnVen purchase “just checks a lot of boxes” in terms of scale, assets, similar strategies, and what Talos is doing from a technology standpoint. EnVen holds 78 MMboe of 2P reserves and 420,000 gross acres in the Gulf of Mexico. The deal also includes about 24,000 boe/d to Talos’ production stream. Consideration for the transaction consists of 43.8 million Talos shares and $212.5 million in cash, plus the assumption of EnVen's net debt upon closing, currently valued to be $50 million at year-end 2022.
Spanish energy group Repsol is putting a 25% stake in its oil and gas exploration division on the market. U.S. fund EIG purchases it for $4.8 billion and builds up a war chest for renewables projects due to the transition of the energy industry to a lower-carbon future. As Reuters reported earlier this year, the deal values the whole business at $19 billion including debt, and may conduct a U.S. stock market listing of a stake in the unit after 2026, according to Repsol’s statement. The process commenced with an unsolicited offer from EIG, Reuters said in June, increasing Repsol's shares to a 14-year high. Moreover, shares grew up after an announcement on September 7 before declining 1.8% by 7:46 GMT. Nevertheless, they outperformed the European oil and gas index, which was down 2.3%.
Williams said on Aug. 8, that it concluded an agreement to support the selling and transportation of certified, low emissions next-gen natural gas from PennEnergyResources LLC. According to the deal, Williams will construct a marketing portfolio to market the natural gas to utilities, LNG export facilities, and other facilities which can efficiently use clean energy. Moreover, the agreement involves a certification process that verifies best practices are being followed to reduce emissions and produce natural gas in an environmentally responsible manner collaborating with an independent third party. The partnership with PennEnergy is a continuation of Williams' strategy to collect, market, and deliver low-carbon natural gas to the end user from the wellhead. PennEnergy’s 378 production wells in southwest Pennsylvania supply the US with natural gas and they have achieved Platinum status from Project Canary’s TrustWell certification.
According to a press announcement on June 29, Baker Hughes got a contract to supply electric-powered Integrated Compressor Line (ICL) decarbonization technology and turbomachinery equipment for an upcoming natural gas transmission project by a subsidiary of Tellurian Inc. – Driftwood Pipeline LLC. Driftwood Pipeline decided that the projects of Lines 200 and 300 would be situated in Beauregard and Calcasieu Parishes in southwest Louisiana and it will be the first time when Baker Hughes installs its ICL technology for pipeline compression in North America. Joey Mahmoud, president of Tellurian Pipelines, says the company expects that the project will give upwards of 5.5 Bcf of natural gas every day, with virtually no emissions. As a part of the agreement, Tellurian makes the initial $240 million pipeline investment as part of the broader Driftwood Pipeline system, which will keep enhanced supply reliability to meet the area’s projected industrial enlargement in a purer, more sustainable way. Baker Hughes has installed over 50 ICL units across the different pipeline and offshore applications, mainly in Europe. The compressors exert a reduced environmental footprint because their hermetically sealed casing prevents emissions from obviating. It is important to mention, that they require minimal downtime as magnetic bearings are resulting in more efficient operations and low maintenance.
Earthstone Energy Inc., based in Texas, announced the transaction on June 28: the acquisition of Titus Oil&Gas which will raise production in the Delaware Basin by 26%. The $627 million acquisition fills the Permian Basin in Eddy and Lea counties, N.M. with 86 net locations on 7,900 net acres of leasehold, while it is not clear how much of the leasehold might be on federal acreage It is Earthstone’s seventh acquisition since 2021, a span that includes the closing of approximately $1.89 billion in acquisitions in the Permian Basin. The purchase of Titus Oil & Gas Production LLC and Titus Oil & Gas Production II LLC, privately held companies backed by NGP Energy Capital Management LLC, is estimated at $575 million in cash and it is the equivalent of $52 million in stock (3.9 million shares of its Class A common stock based on the June 24 closing price). Titus shared that its net production in June was 31,800 boe/d. The company had reserves of approximately 28.9 MMboe. Earthstone is sure its net production will increase, at the midpoint, by 20,500 boe/d (65% oil) in the fourth quarter.
According to CheniereEnergy’s board of directors announcement on June 22, the company declared the further expansion of its CorpusChristi, Texas. Moreover, the LNG plant could come sooner than expected due to the announcement of a final investments decision (FID) related to Stage 3 Liquefaction Project work at the export facility. It will ensure the capacity to ship 10-plus million tonnes per annum (mtpa) from 7 midscale trains. Furthermore, TudorPickering, Holt & Co. (#TPH) declared on June 23, that the possible ultimate capacity of the facility could be in the 11-12 mtpa range given 10.7 mtpa of long-term contracts have been signed with companies such as CPC, PGNiG, Sinochem, Foran, ENGIE, Apache, EOG and ARX CN. Additionally, Cheniere announced two sale and purchase agreements (SPAs) with #ChevronCorp.: Firstly, Chevron will obtain 1 mtpa of LNG from Sabine Pass Liquefaction LLC with deliveries considered to start in 2026. Deliveries will reach full capacity in 2027 and expire in mid-2042. Secondly, Chevron will obtain 1 mtpa of LNG from Cheniere Marketing LLC with deliveries considered to start in 2027 and continue for about 15 years. The purchase price for the LNG under both SPAs will be indexed to the Henry Hub price, plus a fixed liquefaction fee as Cheniere claimed. Since the expansion will have been completed, Cheniere’s aggregate nominal production capacity will be increased to more than 55 mtpa by the end of 2025 compared to 45 mtpa now. It will become a part of the industry-wide decarbonization movement away from coal and oil as this allows Cheniere to provide the global market with additional low-carbon fuels. First exports from the facility are anticipated in 2025.
On June 16 Targa Resources Corp. decided to acquire Lucid Energy Group, located in the Permian Basin, which is a part of Riverstone Holdings LLC and Goldman Sachs Asset Management. Firstly, Targa enlarged due to the recent “blot-on” acquisition of Southcross Energy in the Eagle Ford for $200 million and it will become bigger thanks to the $3.55 billion cash transaction. Targa’s financial position allowed it to utilize convenient opportunities to extend its company so it bought #Lucid using available cash and debt with an estimated pro forma year-end 2022 leverage around 3.5 times. According to Targa’s estimates, the acquisition of Lucid will increase the number of natural gas pipelines by 1,050 miles and add about 1.4 Bcf/d of cryogenic natural gas processing capacity in service or under construction located mainly in Eddy and Lea counties of New Mexico. The investment-grade producers source approximately 70% of current system volumes. According to the press release, a full-year standalone adjusted EBITDA is expected to be between $2.675 billion and $2.775 billion and reported year-end leverage ratio of about 2.7 times. Targa’s updated financial expectations assume NGL composite prices average $1.05 per gallon, crude oil prices average $100/bbl, and Waha natural gas prices average $6 per MMBtu for the remainder of 2022.
Your team’s ESG performance can be greatly improved applying the asset co-location analysis within upstream or midstream use cases. This has been a topic for a discussion at Rextag’s ‘Is ESG Improvement Next Door?’ webinar. We reviewed some cases like curbing gas flaring or renewable energy sourcing to power the fossil fuel infrastructure. Many combinations are available with access to the data Rextag provides on wells, acreages, power lines, substations, and such renewable infrastructure as wind turbines, methane landfills, etc.
On June 5 China Gas Hongda Energy Trading Co. Ltd. has made an LNG sale and purchase agreement (SPA) with Energy Transfer LNG Export, LLC concerning its Lake Charles LNG project. In the course of the 25-year contract, Energy Transfer LNG will provide 0.7 million tonnes per annum (mtpa) of LNG to China Gas on a free-on-board basis. The purchase price is indexed to the Henry Hub benchmark plus a fixed liquefaction charge, with first deliveries expected as early as 2026. Being a premier natural Chinese gas distribution company, China Gas enchants Energy Transfer LNG to sign the 25-year LNG offtake agreement. From the direction of ChinaGas, it will be a significant step along the way to realizing China’s carbon peaking and carbon neutrality goals as it is their first long-term agreement.
Oil output in the Permian Basin in Texas and New Mexico is supposed to go up 88,000 bbl/d to a record 5.219 million bbl/d in June, as the U.S. Energy Information Administration (EIA) announced in its report on May 16. Additionally, gas productivity in the Permian Basin and the Haynesville in Texas, Louisiana and Arkansas will rise to record highs of 20 Bcf/d and 15.1 Bcf/d in June, respectively. Given that this growth has been expected, recent global market changes make forecasting the output even more challenging. Learning how production will change is easier with early activity tracking, a new service recently launched by Rextag – Pad Activity Monitor. With the help of PAM, you are able to monitor well pad clearing, drilling operations, fracking crew deployment and completions with new data collected approximately every 2 days. Additionally, it cuts down activity reporting lag times by at least 98%, from 120-180 days down to just 5-8 days. In order to access reports, charts, tables, and mapping visualizations via Rextag’s Energy DataLink use a web-based application allowing users to filter, download and identify activity on a map or data table. Moreover, customers will be able to set up daily, weekly, and monthly email report notifications.
The EIA forecasts that total output in the main U.S. shale oil basins will increase 142,000 bbl/d to 8.761 million bbl/d in June, the most since March 2020. Oil productivity in the Permian Basin in Texas and New Mexico is supposed to go up 88,000 bbl/d to a record 5.219 million bbl/d in June, as the U.S. Energy Information Administration (EIA) announced in its report on May 16. In the largest shale gas basin, the productivity in Appalachia in Pennsylvania, Ohio and West Virginia will grow up to 35.7 Bcf/d in June, its highest since beating a record 36 Bcf/d in December 2021. Gas output in the Permian Basin and the Haynesville in Texas, Louisiana and Arkansas will rise to record highs of 20 Bcf/d and 15.1 Bcf/d in June, respectively. Speaking of the Permian future output, putting hands on upcoming changes in production has recently been made easier with the new Rextag's service - Pad Activity Monitor. Thanks to satellite imagery and artificial intelligence, customers are able to monitor the oil and gas wells and are provided with near real-time activity reports related to drilling operations. However, it is noticed that productivity in the largest oil and gas basins has decreased every month since setting records of new oil well production per rig of 1,544 bbl/d in December 2020 in the Permian Basin, and new gas well production per rig of 33.3 MMcf/d in March 2021 in Appalachia.
No sooner had the crude prices soared above $100/bbl than the industry professionals believed in an incredible growth of drilling activity in North America’s largest shale patch. Analysts speculate that additional output of 500,000 barrels of oil daily would become a significant part (4%) of overall U.S. daily production. That is going to flatter oil and gasoline prices. Drilling permits in the Permian Basin are persistently growing, averaging approximately 210 at the beginning of April. Moreover, the permits trend is noticed as an all-time high as a total of 904 horizontal drilling permits were awarded last month. Nowadays, learning and analysing the current situation and predicting the future development become easier with early activity tracking, a new service recently launched by Rextag. Rextag's Pad Activity monitor (PAM) allows you to see well pad clearing, drilling operations, fracking crew deployment and completions with new data collected approximately every 2 days with the help of satellite imagery and artificial intelligence. While the increase in drilling will result in higher production, U.S. shale producers will have to overcome several hurdles including labor shortages and supply constraints.
In the midst of the high prices and the U.S. government’s pushing, in the last week, the number of oil rigs increased by 5 and in total makes 557, its highest since April 2020, according to Baker Hughes Co BKR.N. Concerning the gas rigs, they gained 2 to 146, their highest since September 2019. Moreover, crude production was aimed to rise from 11.2 million barrels per day (bpd) in 2021 to 12.0 million bpd in 2022 and 13.0 million bpd in 2023, according to federal energy data. Given that this growth has been expected, recent global market changes make forecasting the output even more challenging. Learning how production will change is easier with early activity tracking, a new service recently launched by Rextag’s Pad Activity monitor (PAM). The overall amount of rigs in the U.S. would grow to an average of 684 in 2022 and 783 in 2023, due to U.S. investment bank Piper Sandler forecast. As Baker Hughes claimed that compares with an average of 478 in 2021.
The joint project to improve and market a low-carbon hydrogen and ammonia production and export facility was presented on May, 6 by Enbridge Inc. and Humble Midstream LLC. Deployment of the facility is taken under the Enbridge Ingleside Energy Center (EIEC) basis close by Corpus Christi. Being the premier export facility on the U.S. Gulf Coast, the EIEC plays a vital role in world energy security and sustainability. Companies plan to develop a utility-scale efficiently low carbon production facility, able to combine both low-carbon hydrogen and ammonia to meet the growing global and domestic demand. It is expected to sequester up to 95% of CO2 generated in the production process in carbon capture facilities, especially ones owned and operated by Enbridge which makes this process a fully integrated low-carbon solution.
Canadian Assets on Sale: Energy Transfer Sells Gas Processing Bussines to Pembina-KKR for $1.3 Billion
Under the agreement, Energy Transfer will sell its 51% interest in Energy Transfer Canada to the Pembina-KKR joint venture, for more than CA$1.6 billion (US$1.3 billion) including debt and preferred equity. KKR's funds already own the remaining stake. TC’s assets include 6 natural gas processing plants with a combined operating capacity of 1.29 Bcf/d and an 848-mile naturalgas gathering and transportation network in the Western Canadian Sedimentary (WCS) basin. While this process is underway, Pembina and KKR will combine their Western Canadian natural gas processing assets into a single, new joint venture entity — Newco, owned 60% by Pembina and 40% by KKR. This new entity is expected to have a natural gas processing capacity of about 5 Bcf/d or about 16% of Western Canada’s total processing capacity.
Great Western Petroleum's assets will be acquired by PDC Energy for $1.3 billion. Via this deal, PDC Energy’s position in the D-J basin increases roughly to 230,000 net acres. Denver-based Great Western has core operations in Weld and Adams counties in Colorado with 54,000 net acres and about 55,000 boe/d (42% oil / 67% liquids) of PDP. As part of the agreement, the acquisition will be financed by issuing 4 million shares of common stock to existing Great Western shareholders and by providing $543 million in cash to the company. All in all, PDC expects to increase its total production by 25% and its oil production by 35% as a result of the deal. The deal should also result in some synergies including a 15% reduction in overall cost per BOE.
Decades of free inventory from one deal: Vermilion Energy buys Leucrotta Exploration for $477 million
As part of its effort to expand its Montney Shale play, Vermilion Energy Inc. recently acquired Leucrotta Exploration Inc. for a net cash purchase price of CA$477 million. Vermilion has identified 275 high-quality, high-return, low-risk multi-zone drilling prospects. Top management believes, these prospects represent 20 or more years of low-risk, self-funding, high-deliverability shale drilling. Assuming the anticipated May closing date, Vermilion is increasing its capital budget for E&D in 2022 to $500 million and increasing guidance for production from 86,000 to 88,000 boe/d to take into account the Leucrotta acquisition.
Crescent Energy closed the acquisition of Uinta Basin assets in Utah that were previously owned by EP Energy for $690 million, a few hundred million dollars below the original price. The accretive deal increases Crescent's Rockies position and adds significant cash flow and a portfolio of high-quality oil-weighted undeveloped sites. In addition to its acquired Uinta assets, Crescent's pro forma year-end 2021 provided reserves totaled 598 million boe, of which 83% was developed, 55% was liquid, and its provided PV-10 was $6.2 billion.
Exxon Mobil Corp. is weighing prospects of selling its assets in North Dakota’s Bakken, after gauging interest from potential buyers — 5 billion is the issue price, at least according to rumors. The price point came about after the news that the oilgiant is in the final round of hiring bankers to help launch the sale. Yet Exxon Mobil itself stays tight-lipped regarding the situation.
Canada is looking at ways to increase pipeline utilization to boost crude exports as Europe seeks to reduce its reliance on Russian oil At the moment, oil exports from Canada to the U.S. are approximately 4 million barrels of oil per day, with a portion reexported to other countries. At the end of 2021 Canadian oil companies exported a record amount of crude from the U.S. Gulf Coast, mostly to big importers India, China, and South Korea. And this will only increase in the future.
By purchasing the gathering and processing assets of Trace Midstream, Williams' existing footprint gains expanded capacity in one of the nation's largest growth basins, bringing its Haynesville gathering capacity to over 4 Bcf/d — increasing more than 200% from 1.8 Bcf/d. The deal also includes a long-term commitment from Trace and Quantum to support Williams' Louisiana Energy Gateway project (LEG), which is aimed to deliver responsibly sourced Haynesville’s naturalgas to markets along the Texas and Louisiana GulfCoast
Looks like Pine pulled the plug on its properties in Caddo Parish, Louisiana, and Harrison and Panola counties, Texas. Which includes a total of 12,500 acres and ownership interests in 10 operated wells with a production capacity of 100 million cubic feet per day along with 18 miles of naturalgas gathering pipelines. Did Pine just give up on Haynesville?
And Petro-Hunt E&P is the new sheriff in town with 21,430 net acres of leasehold in the Basin, production of which surpasses 7,000 bbl/d and 100 MMcf/d respectively. To take advantage of it, Petro-Hunt plans to begin an active development drilling program on these assets in the coming months heavily upgrading the numbers of its 775 operating oil wells and contributing to over 8,100 non-operated wells. Time will tell, however, whether or not this move will be able to deliver such results.
Continental Resources Inc. Invests a Quarter of a Billion Dollars in a Sequestration Project in North Dakota
The investment will happen in the next 2 years. The project intends to capture CO2 from ethanol plants and other sources in Iowa, Nebraska, Minnesota, North Dakota, and South Dakota. Upon aggregation, CO2 will be transported via pipeline to North Dakota, where it will be stored in subsurface geologic formations. The formations will be in the Williston Basin, where Continental Resources has been a dominant producer for more than half a century. At the moment it’s the world's most ambitious carboncapture venture of its kind. The sequestration itself should be underway by spring 2024.
Still waters run deep: after patiently waiting for 2 years, Lime Rock Resources starts the year with a pair of acquisitions worth $358.5 million The two acquisitions include Abraxas Petroleum’s Williston Basin position in North Dakota: about 3,500 acres of land and 19,400 boed of net production, as well as properties situated in Burleson, Milam, and Robertson in Texas from a third party, that contain 46,000 contiguous net acres and produce 7,700 boed as of the closing of the deal. The company intends to intensify its focus on low-risk opportunities and margins, which will significantly boost Lime’s market position going further.
The ever-increasing demand for natural gas exports from the Gulf Coast started a race to further develop Permian Basin. Various companies, including Kinder Morgan and MPLX, are among those looking at building new pipelines in the region due to the demand spike. But Energy Transfer seems to edge past them into the lead since its project strikes as the most economical option for the basin outside of capacity expansions on existing pipelines and could essentially add 1.5-2 Bcf/d of transport capacity with just 260 miles of new pipe.
Evolution Petroleum just spend a fortune on Jonah’s Field right after acquiring Hamilton Dome Field in Wyoming. The price of the transaction is $29.4 million. The Houston-based company aims to diversify into natural gas assets, providing access to the western markets through the Opal market hub, with the optionality to flow to the east. That transaction took effect on February 1. We anticipate closing on or about April 1.
The future of shale is looking bright: economic recovery and a spike in travel lifted oil prices to multi-year highs, helping Continental Resources to a fourth-quarter profit that exceeded Wall Street expectations. Coming off such a high note, the company plans to increase its dividend rates by 15% to 23 cents per share!
The crux of the matter is rather simple: productivity gains of local energy operators have been stable not only because they are drilling better acreage, but also because players finally realized capital efficiency gains. And even if some new obstacles impede Appalachia's growth at the same rate as the Permian or Haynesville, it does not detract from the value of the Marcellus and Utica basins. The Appalachians will still be the top producers at a very competitive pace as long as commercial inventory exists. After all, as long as there is commercial inventory, somebody will have to drill.
Enterprise decided to go in on the Permian Basin. With the surprise purchase of Navitas Midstream for $3.25 billion in cash, the company gained a foothold in the Midland Basin, as it previously lacked #naturalgas or NGL infrastructure apart from downstream pipelines in the region. Enterprise estimates that distributable cash flow accretion will be in the range of $0.18 to $0.22 per unit in 2023, while simultaneously supporting additional capital returns to their limited partners through distribution growth and buybacks of common units.
After probing the initial discovery of eight high-grade hydrocarbon reservoirs, Zephyr Energy estimates that up to 200 wells could be drilled, creating a potential resource of 125 million barrels of oil equivalent in the area. In an investor presentation, Zephyr said that gas rates may reach plateaus of 10 million square cubic feet per day and 500 boepd of liquids. Quite an impressive number. But The key to tapping in such potential lies in the development of hydraulically stimulated resources rather than treating them as natural fracture plays.
Permian Basins gas infrastructure boom: Summit Midstream puts into service a new pipeline system, aimed at reducing gas flaring in the area. Besides ecological concerns, the project will also transport almost 1,5 billion cubic feet of gas per day — enough to supply 5 million U.S. homes every day. According to Federal Energy Statistics, the project cost a whopping $450 million.
Enbridge Inc. finally delivered on several of its long-overdue promises, including the $4 billion Line3 Replacement project. Which consisted of replacing an existing 34-inch pipe with a new 36-inch one for 13 miles in North Dakota, 337 miles in Minnesota, and 14 miles in Wisconsin. Midstream companies, in general, had a stunning Q3. It was the first quarter in two years that no midstream index members cut their dividends.
Altus Midstream and EagleClaw Midstream agreed to combine operations in order to become the meanest midstream player in the Permian Basin! Following this merger, Altus will become the largest natural gas processor in the Delaware Basin, as well as the third-largest for the entire Permian Basin.
Expansion Is The Goal: Ironwood II Completes Asset Merger And Assumes Management of Nuevo Midstream Dos’ Eagle Ford Assets
Ironwood Midstream expanded its operations in the Eagle Ford region through its merger with Nuevo Midstream. Thanks to this, Ironwood II has increased its crude oil and natural gas throughput capacities in the famous shale to approximately 400,000 bbl/d and 410 MMcf/d, respectively. With 390 miles of pipelines, the company manages 245,000 acres of dedicated land.
Sempra Energy would develop the 4.0-mmtpa Vista Pacifico LNG export facility located next to the company's Terminal for Refined Products in Topolobampo in a bid to provide gas from the Permian basin in Texas and New Mexico to Asian markets. Once marketing begins, Sempra's management expects Vista Pacifico to be oversubscribed.
TC Energy splurged $0.8 billion on the project that targets emissions. Well, sorta. According to the idea, existing lines of the ANR Pipeline Company will be expanded to serve markets in the #Midwestern US and simultaneously updated to reduce discharge by 30,000 metric tons CO2e per year - equivalent to removing almost 7000 cars from the road annually. Remarkable goals. With the current timeline, the project will be fully operational by the end of 2025, thanks to long-term transportation agreements secured by ANR.
Texas Cheniere and Swiss Glencore had entered into a free-on-board agreement for approximately 0.8 million tonnes of LNG per annum, starting in April 2023 for 13 consecutive years. This SPA demonstrates the commercial momentum Cheniere has been enjoying and marks an important milestone, as the company lays the groundwork for a final investment decision on Corpus Christi Stage 3, which is expected to occur next year.
Superior Pipeline Co. was successful in its purchase of natural gas gathering and processing assets in central Kansas. These assets consist of a 1,620-mile gathering system and an 85 MMcf/d cryogenic processing plant. No financial details of the deal have been disclosed as of yet. In a bid to amend this top-secret, we narrowed the circle of likely suspects to Durango and Tenawa. Let’s turn to the pipeline maps for further investigation.
TC Energy, the Canadian gas giant, recently announced its environmental, social, and governance goals, as well as emission reduction strategies. The company aims to become 100% emission-free by 2050 while promising to cut greenhouse gas emissions intensity from its operations by 30% by 2030 as an interim measure.
Non-core Permian assets to be sold for $160 million by Diamondback Energy in a massive Drop-Down Transaction
Diamondback Energy is willing to sell some of its Permian Water Assets in order to reduce debt and ensure a steady oil supply through the end of the year. The brokered deal will bring the company some $160 million in cash. Consolidation seems to be the trend in the industry, but for how long?
New standards for carbon capture have been set in North Dakota earlier this month as NDIC greenlights Red Trail Energy’s project. The company will now be able to commercially capture, compress, and inject 180,000 tons of carbon dioxide per year into the Broom Creek Formation on its property for permanent geologic CO2 storage. This ensures that carbon dioxide can be stored safely for generations to come.
The Hunting Season Is Not Over Yet: Exxon Mobil makes a $400 million commitment to Wyoming's carbon capture
Carbon footprint reduction is a new hot trend: Exxon Mobil makes a $400 million investment into its LaBarge facility to expand its carbon capture and storage capabilities by another million metric tons of CO2. Operational activities could begin as early as 2025 after a final investment decision is made in 2022. At present, about 20% of all CO2 captured worldwide each year is captured at the LaBarge. However, as one of the largest of the world's Big Oil companies, it is not the only project in Exxon's pipeline: aside from CCS capabilities, the LaBarge is one of the world's largest sources of helium, producing approximately 20% of global supply
A good asset will not sit on the market for long. After a deal with Berkshire Hathaway fell through, Dominion Energy managed to secure another one for Questar Pipelines in a drop of a hat. And get that, it is better than the former one by more than half a billion! Although not everyone is happy with such decisions, it seems that even Carl Icahn’s complaints won't be able to sway Southwest Gas Holdings’ decision. Though we will have our eyes peeled in any case… If everything goes as planned, a $2 billion deal will be closed before the end of the year.
Comstock Resources decided to go through with asset divestment, selling its Bakken Shale actives for $150M to Northern Oil and Gas. The proceeds from these sales will be reinvested by Comstock Resources Inc. into the Haynesville Shale, at which point the company may acquire additional leasehold and fund drilling activities starting in 2022. Meanwhile, Northern clearly gunning for the pack leading position in the Texas shale play, but whether they succeed or not is remains to be seen.
Penn Virginia announced a rebranding to Ranger Oil on 6 Oct. following the close of the Lonestar acquisition. This Texas oil & gas giant reinvents itself anew, shifting its energy development in the lone star state towards safer and more efficient oil and gas operations. The company's consolidated assets now amount to over 140,000 net acres strategically positioned in the Eagle Ford play of south Texas, making it one of the biggest players. It is anticipated that the full rebranding will be complete by the year-end of 2021. For the full rundown of the situation visit our blog.
The growth of the U.S. oil and gas industry in 2022 will come from smaller companies and private businesses
Forecast: Bank of America expects to see a major bump in US crude oil production in 2022. Such growth from a non OPEC member will impact world oil market balances in times of tight supplies. Still, crude prices should hold well above $70/bbl next year and could, potentially, jump as high as $100/bbl. By 2022, oil output is expected to grow by 800,000 bbl/d, and more than half of that growth will come from #privately-held producers. For a more in-depth analysis of the forecast check out our blog.