Comprehensive Energy Data Intelligence

Information About Energy Companies, Their Assets, Market Deals, Industry Documents and More...

Delays Are Finally Over: Enbridge Reports Strong Third Quarter 2021

Midstream companies had a stunning third quarter. Management teams' confidence in their business is evident in dividend increases and buyback activity. As 2022 approaches, this was the first quarter in two years that no midstream index members cut their dividends.

The completion of projects signals strength to investors, and pipeline giant Enbridge Inc. triumphantly completed several in the third quarter, which included the $4 billion Line 3 Replacement project. It 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.

Enbridge's Line 3 pipeline has been and will remain an important component of its transportation network, delivering crude oil to refineries and to end-users. As a result of the replacement of Line 3, Enbridge will be able to transport crude oil to refineries in Minnesota and neighboring states, as well as in eastern Canada and the Gulf Coast.

It can move up to 760,000 barrels per day of light and heavy crude and NGL and sits more than 1,000 miles from Hardisty, Alberta, to Superior, Wis., which shifts some of the heavy crude load from Enbridge's Mainline system to Line 3.

Nevertheless, Line 3 was not the only major project completed by Enbridge during the third quarter. Its competitors were fierce as well.

For example, a total of $100 million was spent on the Appalachia to Market and Middlesex Extension gas projects. While as a result of the $500 million Southern Access expansion from Superior to Flanagan, capacity rose by 200 000 barrels per day to 1.2 MM barrels per day. On top of that, the company had upgraded compression and installed new natural gas pipelines to boost the capacity of the 1,776-mile BC pipeline system in northeast British Columbia to about 3.5 Bcf/d from 2.9 Bcf/d.

Moreover, September saw Enbridge purchase Moda Midstream LLC in a $3 billion cash deal. For the notice, the newly renamed facility, Enbridge Ingleside Energy Center, was accounted for 25% of U.S. crude oil exports in 2020. And the fourth quarter of the current year should see modest tailwinds from Moda as well.

As part of the purchase, the Viola Pipeline near Corpus Christi, Texas, and a 20% stake in the Cactus II Pipeline were included. It is expected that Enbridge will generate about $305 million in adjusted EBIDTA from the new assets by 2022.

The potential for exponential growth is also there. As the Permian supply recovers through 2024, despite the port's overbuilt capacity for crude oil exports, East Daley's Crude Hub Model predicts increased demand for crude oil exports through the port and the Ingleside terminal.

Back

The Final Stretch: Energy Transfer Pushes For Mariner East Project Ahead Of The Stunning Q3 Results

Energy Transfer's lead in the world's NGL exports booked the company another successive quarter. With a global market share of almost 20%, the company is nigh unstoppable. But will it be enough to, finally, push the Mariner East project over the edge? If everything goes as planned, Mariner East's last segment could be operational by the end of the first half of 2022.

Williams boasts its Q3 results. With a revenue of $2.48 billion, the company beat the analyst estimate of $2.09 billion and also improved upon its own results over the same period in 2020. Mind you, much of this success was attributed to production in Wyoming's Green River Basin's Wamsutter Field and Williams JV with Crowheart.

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.

2022 blog posts