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  • Horiztonal Drilling Metrics Creates Change

    Tracking the metrics for horizontal drilling points to another fundamental change on the land rig scene. Specifically, the number of rigs drilling horizontally for oil totaled 302, according to the latest issue of The Land Rig Newsletter’s Biweekly Report. That compares with 107 such rigs at this time last year. Oil targets comprise 34% of all horizontal drilling, up from 18% last year.

     

    Texas was a substantial source of the increase in oil-directed horizontal drilling. In fact, 95 of the 195 added rigs were in Texas. Not a total surprise, given the strength of the Eagle Ford and growing activity in the Barnett Combo play. The Bakken was another major source of growth, doubling the oil-directed horizontal rig count in North Dakota to 114 as of January 28. Other states making meaningful gains include New Mexico with 19 and Oklahoma with 7.  In Oklahoma, the Granite Wash and Cana Woodford are likely sources of growth. In New Mexico, recent developments in the Bone Spring/Avalon Shale appear likely to drive the state’s horizontal oil count even higher.

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  • The Downside

    From the Biweekly Report with data as of November 5, 2010

    Uh oh, there’s a dark cloud behind that silver lining for onshore drilling: an increasingly stringent regulatory regime for any and all drilling, especially any drilling that is followed by hydraulic fracturing.


    Remember the Exxon Valdez? It cost the industry a lot more than the roughly $7 billion that Exxon shelled out. It’s impossible to put a precise number to the added costs that spill created for the industry. Beyond the specific costs that resulted from new rules such as double-hulling tankers, the Exxon Valdez spill ushered in the Decade of the Environment. It could have been called the Decade of Regulatory Overkill, as the additional animus aimed at the petroleum industry afterwards helped usher in a more stringent regulatory regime across the board, including many areas unrelated to oil tankering.That’s what concerns us now. With newspapers and TV talking heads nattering about the adequacy of the Macondo cement job, why would we assume the discussion wouldn’t drift over the onshore sector for this integral part of the drilling process? Industry already had a battle on its hand regarding fracing and the environment. Now any onshore driller or operator ...

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  • Granite Wash Play Overview


    From the July 2010 issue of The Land Rig Newsletter:


    The Granite Wash play is not developing in a single rock formation like the Barnett or Woodford shale, but in multiple sands within a Pennsylvanian-age sediment package up to 4,000 ft thick. This sediment eroded off the granitic Ouachita Mountains into the Anadarko Basin, hence the play’s name. The play extends across six counties in north Texas: Gray, Hemphill, Lipscomb, Ochiltree, Roberts, and Wheeler; and six in Oklahoma: Beckham, Custer, Dewey, Ellis, Roger Mills, and Washita. Sand packages that are being developed include the Cleveland, Oswego, Red Fork (upper and lower), and Atoka (A and B). Unlike some shale plays that apply a standard well plan across many wells, a standard well plan in this play can only be used in a relatively small area when drilling for any specific sand package. This means that economies of scales for drilling are limited. Rigs will drill vertically to sands at TVDs varying from 8,000 ft to 13,000 ft before going horizontal into a productive zone. Laterals of about 5,000 ft are not uncommon. Operators are still learning which sands produce the best, and the best way to develop the most ...

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  • Other Pennsylvania Actions Target Drilling Industry


    From the June 2010 issue of The Land Rig Newsletter:


    Pennsylvania regulators and legislators are lining up a range of other measures targeting the drilling industry. New permit and administrative fees on drilling were approved to support the non-coal mining program, which implements the Non-coal Surface Mining Conservation and Reclamation Act and the Clean Streams Law. Funding for the program was eliminated from the General Fund in the most recent state budget. Fees to support the program will provide $2,500,000/year. There are also calls from the state legislature for a drilling moratorium, tighter regulation, and increased taxes on all drilling operations. Kathryn Klaber, president and executive director of the Marcellus Shale Coalition, commented, “Unfortunately, this enormous tax hike and misguided call for blanket moratoriums on shale gas production not only puts Pennsylvania on a path to become one of the least competitive energy-producing states in the country, but also threatens critical capital investments, which are essential for continued job growth. Instituting new taxes and an unnecessary moratorium will only drive away jobs—what a missed opportunity that would be.”

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  • What’s Driving Drilling

    From the Biweekly Report with data as of March 26, 2010


    The desire to retain hard-fought leasehold positions. The modern-day “land grab” took off in 800,000 acres in ’08 and another 1.3 million acres in ’09. Leases are typically structured on 3-year terms, suggesting there is much to be drilled and little time to drill it. Hence, we believe the surge in Louisiana and Pennsylvania drilling still has legs, which could be the death knell for gas prices later this year. Companies scrambled to assemble large positions in the Haynesville and Marcellus. In May 2008, Chesapeake unveiled the Haynesville; by yearend some 2.8 million acres were under lease. The pace has been just as breathtaking in the death knell for gas prices later this year.’08 as Marcellus: In late ’07, about 5.4 million acres were leased; operators added roughly 800,000 acres in ’08 and another 1.3 million acres in ’09. Leases are typically structured on 3-year terms, suggesting there is much to be drilled and little time to drill it. Hence, we believe the surge in Louisiana and Pennsylvania drilling still has legs, which could be the death knell for gas prices later this year.    

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  • CT Drilling Finding Its Niche

    From the March 2010 issue of The Land Rig Newsletter:


    Will coiled tubing (CT) drilling ever be more than a rare niche application in the Lower 48 states? A research project by the US Department of Energy in the past decade underscored the potential of using modular hybrid CT rigs to drill ultrasmall-diameter holes to develop marginally economic plays (the Microhole program); that effort opened up a significant shallow Niobrara gas play in Nebraska. Subsequent commercial CT drilling by BP in Oklahoma’s Anadarko basin (horizontal CTD re-entries in the Cleveland tight gas sands) also showed promise, and CT drilling has been a staple on Alaska’s North Slope and in Canada for years.

    But the Lower 48 industry is still loath to pursue this technology, according to a Stewart & Stevenson representative at ICoTA’s annual meeting in The Woodlands, Tex., this month, because US drillers feel that jointed-pipe rigs can drill as fast as CT rigs and provide more flexibility to deal with downhole problems.  Still, CT drilling capabilities are improving as heavy-wall, larger-diameter coil is put to work. The rigs are being used to drill 4–5-in. geothermal holes using 2 7/8 in. heavy wall coil in the western U.S. ...

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