The Pennsylvania Public Utility Commission (PUC) said natural gas producers have paid most of nearly $206 million owed under the drilling impact fee enacted under Act 13, surging past the $180 million that the state had estimated it would take in this year from its new omnibus Marcellus Shale law.
According to the PUC, the 58 producers affected by the fee have collectively paid $197.6 million, or about 96% of the total amount due, $205.9 million. Most of the producers, 35 in all, have paid their entire obligation, while six have paid a portion of their fees and 17 haven't paid anything yet.
Chesapeake Appalachia LLC paid the largest impact fee bill at $30.8 million, followed by Talisman Energy USA Inc. at $26.4 million and Range Resources Appalachia LLC at $23.7 million. All three, which account for 39% of the total amount, have paid their impact fee bills in full. Only two other producers had impact fees of more than $10 million: SWEPI LP, a Royal Dutch Shell plc subsidiary, at $15.3 million; and Anadarko E&P Co. LP at $15.0 million.
"While these figures are indeed staggering by any measure, it also serves as a stark reminder that we must ensure that we have common sense policies in place, especially local zoning uniformity at the center of Act 13, which encourage economic growth, job creation and additional revenue," Marcellus Shale Coalition President Kathryn Klaber said.
Using spud data reports provided by the state Department of Environmental Protection (DEP), the PUC determined that 4,034 horizontal and 419 verticals wells were subject to the impact fee. These well were spud in 2011 or earlier, but for the PUC's fee calculation purposes the first year for all of the wells will be considered as 2011.
Chesapeake accounted for the highest number of horizontal wells (615) subject to the fee, followed by Talisman (526), Range (473), SWEPI (306) and Anadarko (299). Nearly half of the vertical wells subject to the impact fee were drilled by Atlas Resources LLC, which had 214. Cabot Oil & Gas Corp. had the second-highest number of vertical wells at 38. Most of the other producers with vertical wells had fewer than 10.
Pennsylvania had estimated that the impact fee would net about $180 million in 2012, increasing to $211 million in 2013 and $264 million in 2014 (see NGI, April 30). The PUC will set the rate for wells drilled this year on Jan. 31, 2013 using a tiered structure set according to the average price of natural gas on New York Mercantile Exchange for the last day of the preceding 12 months and adjusted for the Consumer Price Index. The payments for the 2012 fee are due April 1, 2013. The fee lasts for the first 15 years of the life of a well and decreases annually.
Although the PUC data was not broken down by county, it is believed that Bradford County will receive the most impact fee money because it led unconventional production during the first half of 2012 (see NGI, Aug. 27). Other counties that should receive sizeable portions of the impact fee pot include Susquehanna, Lycoming, Tioga, Washington, Greene, Wyoming, Westmoreland, Clinton and Fayette counties.
According to the DEP's spud reports, the Catherine Conner 1 well -- a vertical well drilled in Toby Township, which is in Clarion County -- is the oldest active unconventional well to be affected by the impact fee. It was spud by Donna Bricker on Nov. 29, 1979 and is targeting the Geneseo/Burket Shale, which is just above the Marcellus. The DEP said the oldest active unconventional well targeting the Marcellus is the Hunter 1 well in Washington County's Hopewell Township. It was spud by JM Best Inc. on June 18, 1982. Bricker and JM Best have each been levied $10,000 impact fees by the PUC. So far neither has paid the amount due.
"We have mailed each name on the list we received from the [DEP] information about the impact fee and what they need to do to either pay the fee or be exempt from it," PUC spokeswoman Jennifer Kocher told NGI. "If the well is producing less than 90,000 cubic feet of gas a year, it also meets the definition of a stripper well, meaning they do not have to pay the fee. We are hoping to talk with each of the people on the list to clear up these kinds of issues."
Last Tuesday the Pennsylvania Budget and Policy Center, a nonpartisan policy research group, said the state could have collected almost twice the revenue with a severance tax instead of an impact fee. The group said a severance tax modeled on a similar levy in neighboring West Virginia would have raised $387 million between July 2009 and December 2011, based on production data reported by the DEP during that period.
Then-Gov. Ed Rendell, a Democrat, urged lawmakers to consider a severance tax in 2009 in the Commonwealth of Pennsylvania's fiscal 2009-2010 budget address (see NGI, Feb. 9, 2009). But the issue would go on to be debated for another three years. When Republican Gov. Tom Corbett took office in January 2011 along with a Republican-dominated legislature, the debate moved away from a severance tax. Corbett and many of his fellow Republicans had won election on a platform of "no new taxes," and he made clear that included no severance tax on natural gas. Corbett said he could support an impact fee to help local communities repair any damages from gas development (see NGI, March 28, 2011).
According to the Washington, DC-based Resources for the Future's Center for Energy Economics and Policy, the national average for severance taxes is about 11 cents/Mcf (see NGI, Aug. 13). West Virginia, a mid-range volume producer, charges 12.3 cents/Mcf, which equates to a 5% severance tax.
Act 13, which was signed into law by Corbett in February, amended Title 58 (oil and gas) of the Pennsylvania Consolidated Statutes and empowered the PUC to collect the fee on behalf of local governments (see NGI, Feb. 20). The law gives Pennsylvania's counties the choice to collect an annual per-well fee from operators and is set annually.
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