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Texas Oil & Gas Drilling Outlook Including Permian Basin and Eagle Ford

Texas Oil & Gas Drilling Outlook Including Permian Basin and Eagle Ford

  • April 2017
  • 87 pages
  • ID: 4895321
  • Format: PDF
  • By Freedonia

Summary

Table of Contents

Oil and gas drilling in Texas is expected to show robust growth between 2016 and 2017, driven by activity in the Permian Basin. The Permian Basin is composed of resource-heavy strata. As a result, drillers are able to recover oil and gas from this region at some of the lowest breakeven costs in the country.

In recent months, investments have poured into leases and infrastructure expansions in the Permian, despite the low WTI crude oil benchmark price. Additionally, innovations in unconventional drilling techniques are expected to increase IP rates and EUR, allowing wells in both the Permian Basin and elsewhere to be more profitable.

Texas Oil & Gas Drilling Outlook answers these questions and more:
- What is the current status of drilling in the Permian Basin and where is it headed?
- How will the crude oil prices affect drilling in the Eagle Ford Shale?
- What is the outlook for other plays in Texas?

Infrastructure Update: Two New Oil Refineries Planned in Texas
Earlier this spring, MMEX Resources and Raven Petroleum, a subsidiary of Raven Resources Group, announced plans to construct two new oil refineries in Texas. The refineries are planned for the Permian Basin and Eagle Ford Shale regions, respectively.

The MMEX facility is expected to have 50,000 BOPD capacity, while the Raven refinery is expected to have a capacity of 55,000 BOPD. This announcement is significant, given the infrequent construction of refineries, especially ones with large capacities. While large capacities are generally thought of as 100,000 to 200,000 or more BOPD, these new refineries will be largest in approximately 40 years in the United States.

Key Findings in the Texas Oil & Gas Drilling Outlook Study:

Permian Basin Leads Drilling Trends in Texas
While Texas currently occupies the largest share of drilling rigs and is drilling the most wells in the US, the Permian Basin, the most promising play in Texas, is driving activity in the state. The Permian Basin, identified by the USGS in 2016 as containing the largest contiguous recoverable volume of resources in US history, is valued for its unique geology.

The region possesses a stratigraphy that has multiple stacked layers of proven resources. As a result, operators have flocked to the play, investing nearly $30 billion dollars in leases since June of 2016. The Permian Basin has the best drilling economics in the country and the drilling statistics are a reflection of that profitability.

Technological Advances in Unconventional Drilling Lower Breakeven Costs
Since the rise in popularity of unconventional drilling techniques, specifically hydraulic fracturing of horizontal well bores to retrieve resources from low permeability rock, the technology has continually improved. As of today, hydraulic fracturing is being performed on longer lateral lengths with high proppant densities, tighter frac clusters, and more frac stages. Additionally, drilling speeds are faster, multi-well pads are increasing, and multi-lateral wells are more common.

All of these advances increase well profitability, either decreasing overhead costs on a per well basis or increasing the IP rate and EUR of a well. The lower the overhead costs equals a lower breakeven cost, and the more money that can be potentially made off a well translates to better overall drilling economics. Wells can be drilled with lower and lower benchmark oil prices.

Drilling Services Costs are Deflated Due to Lowered Drilling Activity
Following the collapse in benchmark oil prices in 2014, companies providing drilling services were forced to decrease prices to compete in a bear market. Drilling activity around the country slowed because the breakeven costs associated with drilling most wells become unattainable. Subsequently, drilling services were and are being delivered to operators at discounted rates to maintain their business amongst their competitors. While some of the cost savings currently found in drilling wells across the country is a result of technology, an equal contributor is the currently lower drilling services costs.

Outside of the Major Plays, Horizontal Drilling is Decreasing
Outside of major plays like the Permian Basin, a majority of wells drilled are more traditional in composition. Where operators are unable to meet breakeven costs as result of unique geology, ample infrastructure, or high IP rates, wells are being drilled vertically in conventional plays. Since unconventional drilling techniques come with higher costs for drilling and completion, drillers are opting to drill vertical wells in proven conventional plays that meet the bottom line.

Study Coverage
This study presents historical data (2015 and 2016) and forecasts (2017 and 2018) by play (Permian Basin, Eagle Ford Shale, Barnett Shale, and Haynesville Shale) in wells drilled, footage, and active rigs. Historical data is presented for drilling permits. Additionally, data is analyzed by well trajectory, resource, and sub-basin, where applicable. The study also evaluates drilling rates, drilling costs, land acquisitions, and infrastructure.

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