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Heater-Treaters on the rise in North Dakota?


Responding to pressure to reduce the volatility of North Dakota crude oil after the train disaster in Lac-Megantic, Quebec in 2013 which killed 47 people and another derailment and fire in North Dakota that same year, the North Dakota Industrial Commission (NDIC) passed standards on December 9, 2014 to require oil-conditioning equipment at the well head to separate production fluids into their gas and liquid components, thereby reducing the volatility of the crude.

The standard requires producers to heat crude oil to at least 110 degrees F. at a pressure of 50 psi., effective April 1, 2015. The standard device commonly used to accomplish this is known in the industry as a “heater-treater. See image below.


The order requires a Reid Vapor Pressure (RVP) of 13.7 psi. “RVP” is a measure of gasoline volatility indicated in pounds per square inch, the higher the RVP the more quickly it evaporates, RVP at normal atmospheric pressure is 14.7 psi. Just how many heater-treaters may be required is a heated subject of debate between the State regulators and the industry.

Two recent State announcements attempt to provide some indication of where things might stand. The North Dakota Department of Mineral Resources has indicated that 80% of Bakken crude has an average RVP of 11.8 psi, less than the requirement and therefore in compliance. State inspectors recently reported that 55% (165) of the roughly 300 existing heater-treaters operated within the guidelines, 33% (99) were operating at lower temperatures and 12% (36) applied no heat to crude oil. The 12% is believed to represent smaller operators who could be severely impacted by the new rules.

The 800 pound gorilla in the room with these statistics though is what percentage of the existing wells have no heater-treaters, potentially a lot more than 300 given the thousands of wells in North Dakota. A search of the DI database for existing directional wells in North Dakota reveals 12,994 directional wells. Accepting the State’s 80% rule and taking only 20% of the 12,994 wells leaves 2599 wells without equipment. To be conservative we will assume as many as 6 wells could be treated with one heater-treater (the number will actually vary depending upon production and equipment capacity) the additional units would total 133 (2599/6 – 300 = 133). If labor and equipment were to run $100,000 per installation costs would be in the neighborhood $13,300,000 to reach compliance.
Due to the uncertainty of making accurate predictions of total wells in North Dakota, I chose to use only newer horizontal wells in this example. However a conservative estimate of the total number of active wells in North Dakota would be upwards of 25,000 wells. In which case, the projections herein could easily double. Not to mention the likelihood of wildly varying installation costs, all assumed to be occurring over 90 days in the dead of winter. Alas, as most field disputes in remote areas of the oil patch one can see that this controversy is just beginning. Given the 60% decrease in the price of crude oil in January alone, the only certainty appears to be a bad April Fool’s joke for a lot of operators. As always DI Analytics will be watching the data to sort out fact from fiction as the information becomes available.

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Bob Black

is the Director Analytics and Geology for Drillinginfo. He works with internal and external stakeholders to create value added predictive analytics and insights into best practices within unconventional shale plays. He has over 30 years of experience in the Oil & Gas industry. He joined Drillinginfo in 2008 as the Director of Leasing Services where he oversaw the collection of lease data throughout the United States. Bob received his Bachelor of Business Administration in International Business and Master of Business Administration from the University of Texas at Austin.