- Tight Gas & Oil
- Gas Hydrates
Hart Energy canvasses service providers, E&P companies, and consultants weekly across the four service lines of pressure pumping, downhole completions, land drilling and well servicing, seeking information on pricing, current activity drivers, current practices, and near term outlook. Surveys rotate through the major unconventional plays on a quarterly basis.
Survey results are compiled in executive summary form with quantitative and anecdotal comments and published by service line approximately twice weekly. Unconventional coverage involves two major unconventional markets monthly in a rotation that includes the Eagle Ford, Permian Basin, Bakken, Marcellus (Appalachian Basin), the Midcontinent, and alternating coverage of the dry gas basins such as the Barnett, Haynesville, and Barnett, along with other markets such as the non-Bakken Rockies.
The oil price bump in June created additional inquiries on the availability of drilling rigs in Appalachia. However, when oil fell in early August, inquiries for rigs in the region also softened.
Moving to multiwell zipper fracks could cut that time to five days, or by as much as 30% per well, according to participants of Hart Energy's Heard In The Field survey.
Meanwhile, a blanket of homogeneity overlies Appalachia completion techniques. The only exception regionally involves some of the hotter, deeper Utica wells, according to Hart Energy's Heard In The Field report.
Well service work has focused on necessary maintenance and little else in the Marcellus Shale area, according to Hart Energy's Heard In The Field survey respondents.
Drilling activity in the Marcellus Shale is down by more than 80% from the peak as operators opt to complete the low number of drilled wells at discounts costs.
Drilling contractors in the Appalachian Basin see a bleak 2016 as capacity utilization falls to 25%. Pricing for rigs suggests only a few long-term contracts remain in the region.
Hourly workover rates dropped 10% in the last 90 days, according to Hart Energy’s Heard In The Field report. Contractors say the region needs gas prices above $3 before activity improves.
Operators are sticking with “tried and true” in the Marcellus Shale until commodity price recovers, including large proppant loading on standard slickwater fracture stimulation treatments.
Winter-time natural gas demand has kept activity for Marcellus well stimulation providers steady, albeit at low levels. In the meantime, providers wait for prices to improve.
Marcellus operators are doing only what is necessary to keep wells flowing. A few service providers are noting that work volumes have remained unchanged over the last 90 days.
Rig count continues to decline in the Marcellus region, the supply of drilling rigs remains excessive, and contractors peg utilization in the low 40-percentile range.
Well stimulation service providers note the upper Marcellus remains the most active market because of cost advantages. Meanwhile, activity in the lower Marcellus and Utica has slowed.