ALRDC Technical Library

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Common Problems and Solutions Sucker Rod Pumping Applications
by: Mark W. Mahoney — Added 9/20/2009 12:00:00 AMSWPSC - Beam Pump General


This paper will cover common problems and misunderstandings that lead to sucker rod pumped well failures and some of the solutions to avoid failures and optimize the sucker rod pump system.

The mechanics of the sucker rod pump design and modifications to improve performance in harsh well environments and failure data collection and performance measurement will also be examined.

DUAL DISPLACEMENT PUMPING SYSTEM
by: Humberto Leniek — Added 6/11/2009 12:00:00 AMSWPSC - Beam Pump General


The need to produce from secondary recovery wells, where large volumes of water are necessary to lift in order to produce oil, made possible an innovative artificial lift option using a dual displacement pump reciprocated either with sucker rods or coiled tubing. This paper describes a dual displacement pump and pumping systems pumping unit. The system consists in reciprocating a plunger of a down hole pump, either with coiled tubing or sucker rods, where both motions are utilized to lift fluid to surface. In the down stroke production is conveyed to surface through the annular space between sucker rods and production tubing, or through the ID of the coiled tubing. In the up stroke fluids are conveyed to the surface through the annular space between sucker rods and production tubing, or between CT and production tubing. The full use of the pumping cycle allows to produce up to 80% more fluid per unit of time, making his production system the ideal option to reduce lifting costs in

Extending Run Times in Deviated Wells
by: Gary Abdo — Added 6/12/2009 12:00:00 AMSWPSC - Beam Pump General


A greater number of deviated wells are being drilled to increase production and prolong the life of a well. Many times the build rates are very high and result in a well that is very difficult to artificially produce. Designing a pumping system that will give extended run times is an important part of maximizing profits. Working with Crimson Resources in the Bakersfield, CA area and ChevronTexaco in the Eunice, NM area, R&M Energy Systems has completed several case studies. We will examine these studies, showing best practice and cost saving.

FIELD PERFORMANCE OF INTERNALLY PLASTIC COATED TUBING IN ROD PUMPED WELLS
by: Elton J. Smith, Chris Holley, Scott W. Long — Added 6/11/2009 12:00:00 AMSWPSC - Beam Pump General


This paper compares the reduction of tubing leaks in rod pumped wells installed with non-internally coated (Bare) tubing to wells installed with internally plastic coated (IPC) tubing.

Bare tubing and IPC tubing performance has been evaluated to present the following: (1) the best tubing design to reduce tubing leaks, (2) the impact of IPC and Bare tubing on total downstroke friction and (3) parameters to better design with IPC and / or Bare tubing.

Tubing leak performance data has been evaluated from the 145 wells operating in the Preston Spraberry Unit “Best Practices” Project.

Tubing leak performance has also been evaluated for 125 Spraberry wells operating outside of the Preston Spraberry Unit.

Pioneer Natural Resources 10 Year "Best Practices" Program and Database
by: Albert S. Garza, Danny Hernandez, Scott W. Long — Added 9/20/2009 12:00:00 AMSWPSC - Beam Pump General


August 17, 2006 marked the 10th Anniversary of the Pioneer Natural Resources, Preston Spraberry Unit (PSU) “Best Practices” Failure Reduction Program. This 10 year partnership between Pioneer Natural Resources, Flexbar Inc., Norris Rods, Tommy White Supply and Kel-Tech has resulted in significant reductions in downhole failures and savings in operational costs for Pioneer Natural Resources.

The 10 year performance (FPWPY) for this 150 well, PSU “Best Practices” program has resulted in a 94 % reduction in Tubing Leaks, 75 % reduction in Rod Failures and an 80 % reduction in Pump Failures.

The 10 year performance (Dollars Saved) for this PSU “Best Practices” 150 well project is estimated at $17.9 million utilizing the 2006 failure costs of $16,000 per Tubing Leak, $9,000 per Rod Failure and $8,000 per Pump Failure.

This 10 year savings represents an average of $1.8 Million per year for this 150 well failure reduction program

POWER EFFICIENCY OF SUCKER-ROD SYSTEMS
by: Gabor Takacs — Added 6/11/2009 12:00:00 AMSWPSC - Beam Pump General


The paper investigates the power conditions of sucker-rod pumped installations. The power losses occurring in a rod pumping system are detailed and are grouped into surface and subsurface losses. The system’s overall energy efficiency is defined and is broken into its constituent parts. After a detailed evaluation of the possible energy losses, a three-term formula is proposed in which the most important term is the lifting efficiency that describes the downhole energy losses in the rod-pumped well.

When evaluating the energy efficiency of sucker-rod pumped installations, the calculation of the rod pump’s useful power plays a decisive role. The paper proposes a new formula to properly describe the useful power exercised by the downhole pump that represents the minimum power requirement for lifting the given amount of liquid to the surface. Through worked examples, the paper shows the advantages of using the proposed formula and recommends its future use for the calculation of the ro

Using Varible Frequency Drives on Rod Pumping Installations
by: Shawn Anderson, James Franklin, Dale Hawthorne — Added 6/12/2009 12:00:00 AMSWPSC - Beam Pump General


Variable Frequency Drive (VFD) technology has been employed in a wide variety of applications in many industries in recent years. Application of VFD to the rod pumping system has allowed pumping speed to be adjusted in real time by the POC, eliminated sheave changes as well conditions change, reduced power consumption, and allowed continuous pumping of wells producing formation solids. This paper will review the installation, operation, benefits and economics of installations on new and existing wells at several locations in West Texas operated by BP America