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San Juan Basin Bankruptcies and Acquisitions - Southland Royalty Co.
Sabina Kraushaar, Geologist at SMK Geoscience

It has been a wild ride with the price of oil dropping into uncharted territories at less than $0/barrel in April of this year. These are difficult times for any operator, many have already declared bankruptcy and others are barely hanging on. It is notoriously difficult to predict the price of oil, but one can only hope that things will recover so small operators can make money again. The silver lining is that there is a great opportunity right now for companies and investors who are lucky enough to have the capital to spend. Everything is on sale!

As an upstream consultant working in the San Juan Basin, I've been using Rextag Energy Datalink and local experience to quickly evaluate operators in the basin. With the recent wave of oil and gas company bankruptcies, let's take a look at a specific operator, Southland Royalty Co., headquartered in Fort Worth, Texas. Southland Royalty Co has received more than $1 billion in capital commitments from private-equity firm EnCap Investments and filed for bankruptcy in January of 2020, according to public court documents. In 2015, Southland Royalty acquired assets in the San Juan Basin of northwestern New Mexico from Energen for $395 million. Just last week, Southland Royalty sold its San Juan Basin assets to MorningStar for $17.3 million. This price is just a small fraction of the previous value of the assets.

While we cannot know exactly how MorningStar arrived at their bid price, I will go over the basics with an emphasis on the data needed to evaluate Southland Royalty's acreage in the San Juan Basin. This bankruptcy and sale are interesting because of Southland Royalty's extensive acreage position in a mature basin with potential geologic upside. The San Juan Basin is located in northwestern New Mexico and has historically been a major producer of coalbed methane from the Fruitland Formation (1980's - present). The operators with the highest recent production numbers in the San Juan Basin are Hilcorp Energy Company, BP (BP's San Juan assets were recently acquired by IKAV), Red Willow Production Company, followed by Southland Royalty, Logos Operating, Enduring Resources and DJR Operating (Figure 1).

Figure 1. Historical San Juan Basin Oil & Gas Production since 1993 from Rextag Energy DataLink.

In the past seven years, the oily Cretaceous Mancos formation has opened a slew of unconventional activity in this old gas basin (Figure 2). The Mancos formation is a ~1,000 feet thick black marine shale, with interbedded sandstones that have higher porosity (4% - 10%) than the organic-rich oil sourcing shales. These tight sandstones within the Mancos have become the target for unconventional horizontal drilling in the San Juan Basin. As shown in Figure 2, total oil production in the San Juan Basin was roughly 2.5 million barrels per year in 2012. Just 3 years later, as operators started drilling horizontal wells in the Mancos, cumulative oil production in the San Juan Basin breached 9 million barrels per year. With three stacked lateral targets within the Mancos (the Gallup, El Vado, and Mancos Silt), operators have drilled 7,000'+ horizontal wells with many successful results.

Figure 2. Cumulative oil production from all wells in the San Juan Basin by year from Rextag Energy Datalink. In 2013, oil production in the San Juan Basin began to rapidly increase as operators began drilling horizontal wells in the Mancos formation.

To evaluate Southland Royalty's acreage, fast and accurate production data and acreage maps are imperative (Figure 3). Southland Royalty operates about 1,085 wells in the San Juan Basin with average cumulative gas production of ~500,000 MCF/month in 2019. The production is mainly gas from the Fruitland and Dakota formations. Typically, an engineering team will give value to the current production, subtract value for plugging liabilities, and then it is the geologist's job to give value to open acreage with untapped geologic potential.

Figure 3. Southland Royalty Company's San Juan Basin acreage, cumulative and monthly production from Rextag Energy Datalink.

Putting a price on undrilled acreage with geologic upside is usually the factor that can vary the most when evaluating a prospect and can give a bidder the competitive advantage. The data necessary for this estimate includes well logs, geologic formation tops, structure and thickness maps, rock core to tie into petrophysical models, and local geologic expertise.

Southland Royalty's southern San Juan Basin acreage is out of the basin-center gas window and is a long trend of recently drilled Mancos horizontal oil wells (Figure 4). These wells are averaging almost 400 BBL/day of oil in the first month of production (Figure 4). In this case, a buyer will at least consider the potential Mancos oil geologic upside in the acquisition process, and then decide if they want to include upside in their bid.

Figure 4. Decline curves for San Juan Basin Mancos/Gallup oil wells spud in the past 7 years, with Southland Royalty Co acreage shown for reference from Rextag Energy DataLink.

Quantifying the value of an asset is difficult to do without an experienced team, local knowledge, and fast access to land, production, and well data. But now, more than ever, big public datasets are becoming easy to access and manipulate. Going forward in this competitive environment, big data will be key in making good business decisions, and in the next few months, there will be many other buying opportunities as distressed companies are forced to sell their assets. Happy bidding!

About Rextag Energy DataLink:

Energy DataLink is an innovative solution that provides aggregated, organized, structural and non-structural information needed by professionals across all sectors of the energy supply chain. By interconnecting data sources and providing multi-level data filters, Energy DataLink provides industry-leading energy data via a simple, online interface.

Click HERE to download PDF and MSExcel reports related to this article.

About the Author:

Sabina Kraushaar is a geologist at SMK Geoscience consulting services. SMK Geoscience offers high quality geologic and geotechnical services to the upstream oil and gas industry and is experienced working in the Four Corners and Rockies areas of New Mexico, Colorado, Utah, Arizona Wyoming, and Nevada. SMK Geoscience provides prospect generation and evaluation, database management, well-log correlation, mapping, and petrophysical modeling.

Sabina Kraushaar can be reached HERE.

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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.

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