Presentation on theme: "9 th Annual Sucker Rod Pumping Workshop Renaissance Hotel Oklahoma City, Oklahoma September 17 - 20, 2013 Breakout – SRL Horizontals Norman W. Hein, Jr.;"— Presentation transcript:
9 th Annual Sucker Rod Pumping Workshop Renaissance Hotel Oklahoma City, Oklahoma September 17 - 20, 2013 Breakout – SRL Horizontals Norman W. Hein, Jr.; P.E. Chief Technology Professional NPS & Norris/AOT Group Companies
Discussion Summary Attendees – Total = ~40; lasted ~1hour –28 operators –11 service/manufacturers –1 consultant Where to put the pump (in vertical/above the curve, in the curve, pushed out in he horizontal)? –It depends on what drilling department left in the well Normally below where the fluid level is But in a place where the pump barrel length is straight Sept. 17 - 20, 2013 2013 Sucker Rod Pumping Workshop2
Horizontals Cont –Some not aware of ROT on placement and effect on failures that was developed from original SRL horizontals in the 80s Put above the curve lowers production but has lowest failures Put in the curve has some production increase but 2* failures Put in the horizontal for max drawdown and production but 1.5 * failure than placed of above curve Sept. 17 - 20, 2013 2013 Sucker Rod Pumping Workshop3
Horizontals cont –Some in Canada aware of pump placement; but, really depends on what drilling department to drill especially the tangent; straight sub vs. bent sub Speaking of drilling dept… –Most operators meet with drilling to discuss planning a well before drilling –But few had prerun rod string design software using plan to decide how it affected resulting side loads on rod string –This was important to some operators and one service company due to drilling from pads and potential for well interference especially where highest loads occur Sept. 17 - 20, 2013 2013 Sucker Rod Pumping Workshop4
Horizontals cont –Most didnt know about controlling undulations while drilling the horizontal or considered the effect on production for the life of the well especially if gas produced –Almost all operators said wells in the future are planning to be horizontals with few verticals; but, some will be drilled depending on lease line position, infill/replacement –Orientation of well, toe up, two down, or horizontal depend on if oil or gas well, lease line, rock/ producing formation orientation; but some said economics determined toe down was best Sept. 17 - 20, 2013 2013 Sucker Rod Pumping Workshop5
Horizontals cont What was being done for handling gas? –One operator waited for horizontal to produce awhile to clean up debris before running poor boy since pumps placed above cure while some used combination separator & tubing anchor that screwed into end of tubing –But there was concern about effect on equipment if solids (sand) produce; but, some ran old pump barrel as poor boy mud anchor –One operator looked further in the design for the separator Oryx ran with oriented /bent dip tube; found that a rubber hose was used while being placed in ~60 o tangent Sept. 17 - 20, 2013 2013 Sucker Rod Pumping Workshop6
Horizontals cont –Self orientating separator was discussed and some had experiences operating this; but, found intake was normally smaller than normal pump intake which resulted in flow restriction and decreased production requiring setting expectations lower since only 50% successful –Related to gas separator was use to help rod pump controller work; needed slowing down N from 6 to 5 spm but then able to consistently detect pump off Sept. 17 - 20, 2013 2013 Sucker Rod Pumping Workshop7
Horizontal cont Corrosion control for horizontals –Batch treating down annulus flush with produced fluid –Monitoring with coupons so chemical company not over treat Use of sinker bars in horizontals –Having mixed results from an operator –Software recommends putting them in curve but operator concerned about increased wear –Ran design program with them installed above curve; but, resulted in program saying 1000 lbs compression Sept. 17 - 20, 2013 2013 Sucker Rod Pumping Workshop8
Horizontal cont –A service company rod string designer recommended running 300 to 500 feet max above the curve/kick-off; but, need to see if can design to reduce PPRL, especially by using smaller rod string –However no one said they validated rod string design after installing and pumping down the well to stabilized producing conditions Sept. 17 - 20, 2013 2013 Sucker Rod Pumping Workshop9
Sept. 17 - 20, 2013 2013 Sucker Rod Pumping Workshop11 Copyright Rights to this presentation are owned by the company(ies) and/or author(s) listed on the title page. By submitting this presentation to the Sucker Rod Pumping Workshop, they grant to the Workshop, the Artificial Lift Research and Development Council (ALRDC), and the Southwestern Petroleum Short Course (SWPSC), rights to: –Display the presentation at the Workshop. –Place it on the www.alrdc.com web site, with access to the site to be as directed by the Workshop Steering Committee. –Place it on a CD for distribution and/or sale as directed by the Workshop Steering Committee. Other use of this presentation is prohibited without the expressed written permission of the author(s). The owner company(ies) and/or author(s) may publish this material in other journals or magazines if they refer to the Sucker Rod Pumping Workshop where it was first presented.
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