A liner is probably the most critical string of pipe set in a well. One of the most common problems encountered in liner cementing is the migration of gas in the annulus during the cementing operation. This can lead to a leaky liner top and a subsequent remedial squeeze job. By using proper cementing techniques and materials, including mud removal procedures, gas migration can be minimized and the need to squeeze liner tops can be reduced. Recently, several liners were set in wells in Lea County, New Mexico, in which different drilling conditions and problems were encountered (Table I). This paper presents case histories of these wells and the cementing techniques and systems used to combat these problems.

Sand, Iron Sulfide, Frac Sand, and other particulates produced with the fluid often cause sucker rod pumping problems that shorten sucker rod pump runs to unacceptable times, or actually prevent successful use of sucker rod pumping. Common sense methods of successfully dealing with these particulate problems will be covered as will developments in sucker rod pumps for successful particulate production.

When dealing with cementing operations with problematic formation issues, achieving satisfactory top of cement (TOC) is essential. A central Texas operator encountered zonal isolation challenges that resulted in inadequate TOCs. One of those challenges was achieving a density both above the pore pressure and below the fracture gradient. In some wells, this density window was as narrow as 0.02 to 0.04 psi/ft. Karsts and tectonic-fractured formations exist in this field, which often result in uncovered zones and TOCs at unacceptable levels. Formations such as these, with heavy erosion and cave-related brecciation, can have huge voids at volumes that are nearly impossible to measure. To meet regulatory requirements and achieve successful zonal isolation, competent cement sheaths are necessary. Initially, expensive cement-squeeze applications evolved as the zonal isolation effort was initiated in these trouble wells. However, it was decided to use a conformance product to allow the cement column to exist at a high enough level to be deemed a successful solution without the aid of the squeeze application. This
paper presents a case history of several central Texas wells in which satisfactory TOC was difficult to achieve. The challenge was to get cement high enough to meet regulatory requirements, without having to perform a squeeze job. The wells discussed exist in an environment with washed out formations occurring in a narrow window of design density. The design criteria involved overcoming these washed out regions that consume cement volume. The service company provided a solution of using a conformance product to achieve adequate TOC without the aid of a squeeze application. This paper compares several wells before and after using this water super-absorbent polymer procedure, demonstrating an improved percentage of adequate TOCs and significant cost savings to the operator.

Sucker rod connection failures seem to be a problem to some operators, while others do not seem to have the same problems. The connection should be the strongest link in the sucker rod string while the rod body should see more failures. There are three main classifications for the connection failures. These are: manufacturing discontinuities or defects, mechanical damage (including handling and make-up procedures), and loss of displacement (LOD). This paper will: discuss the API industry connection, discuss the three failure classification areas, and provide many
example pictures of the failure causes Additionally, recommendations will be provided on how to prevent future connection failures.

Sucker rod coupling friction values are used by rod design software to calculate rod loads for bare steel tubing on steel couplings. The friction values for sucker rod couplings on HDPE lined tubing are not yet known or defined. Therefore, rod load calculations in HDPE lined tubing are problematic. Tests were performed to compare the coupling friction in HDPE lined tubing compared to bare steel tubing at various temperatures and side loads. The objective was to find the drag ratio of rod couplings on HDPE lined tubing to that of bare steel tubing at various temperatures. The data was used to develop an equation to calculate the drag in HDPE lined tubing compared to that of bare steel tubing as a function of temperature. Although not quantitatively analyzed in this study, a side load capacity difference between HDPE lined and bare tubing was also observed

After consideration of all component parts in a sucker rod pumping installation, it is believed that the sucker rod string most directly affects the action and performance of the entire system. Sucker rod behavior, in transferring the forces and loads that are involved, determines the action of the subsurface pump. The load imposed on the surface equipment are attributed directly to the inherent characteristics of the sucker rods. The allowable stresses , range of loads imposed and speed of operation, which a sucker rod string can withstand without excessively frequent breakage, limit the economic depth and capacity of an installation.

It is important to know the cause of sucker rod failures so that the cause can be eliminated or guarded against. This paper presents numerous illustrations of the most common forms of sucker rod failures and explains the cause of these failures. Corrosion is the greatest cause of sucker rod failure and the bulk of the illustrations are of sucker rods that have been damaged by corrosion. A brief description of the basic corrosion process is included.

The most common type of sucker rod failures (pin failures) can be reduced by application of load range effects. This paper introduces a simple graph which can be used as a guide to limit peak loads based on load range for increased sucker rod service life.

There are very few papers that present the actual fatigue data for various grades of sucker rods from a variety of manufactures. This paper will provide information on the testing being conducted by one sucker rod manufacturer and the performance of high strength API D grade rods versus non-API extra high strength rods for air fatigue in rotary bending tests. Additionally, information will be provided on the relevance of these results and on the next phases of fatigue testing that is being planned.

This paper discusses the history of rod guides, early attempts in their development, types of guides presently available, a study of the proper use of guides, and a recommended procedure for placement of guides.

This presentation will provide a review of published information where sucker rod lift has been used to produce highly deviated and horizontal wells. Additionally, some useful recommended practices from equipment suppliers will be included on design, selection, and changes to consider for rod lift equipment when used to produce horizontal versus vertical wells.

Most sucker rod pin and coupling failures are considered to be related to loose couplings. Correct pin prestress offers the best way to prevent loose couplings and the "circumferential displacement" method offers the best way to achieve correct pin pre-stress.

This paper discusses the many types of balls and seats that the industry has to offer for varied well conditions, and also explains the proper use of plungers, barrels, tubes, cages, and other accessories. Pump parts destroyed by corrosion and abrasion are displayed, as well as sample pumps constructed to resist such attack.

Presentation will cover care and handling best practices for a sucker rod pump from the pump shop to the well bore and introduce a new tool for safely lifting a sucker rod pump from horizontal to vertical at the well head. For years, long and heavy insert pumps have been lifted into the vertical position to be run into the well by various means, some causing damage to the pump and contributing to failures. In most cases this process places undo stress on the rig crew, as they have to support the entire weight of the pump while it is lifted and it places them under a suspended load. These safety concerns can be reduced with the use of this tool and recommended procedures.

One of the principal causes of subsurface failures is corrosion. Corrosivity of well fluids is primarily related to hydrogen sulfide and/or carbon dioxide gases in the produced water. Optimum utilization of corrosive-resistant materials for component parts of sucker rod pumps has been the more economical practice in Exxon's operation as compared with the use of corrosion inhibitors and less expensive metals. Past performance of pump part metals was studied to provide guidelines in upgrading the pump part metallurgy. Using a computerized data bank, over 8,000 pump runs were analyzed from 26 major folds within the West Texas and Oklahoma areas, most of which contained hydrogen sulfide in the produced fluid. General guidelines for pump part metals selection were established. The study indicated that average pump part service of at least I2 months should be expected with proper metallurgy selection.

Sucker Rod pumping as it is used in today's oil field, evolved from the waterwell wooden sucker. Early history includes rope used for lifting water in irrigation systems. Increasing rod string performance lift through manufacturing quality control, proper string design, correct handling and control of environment.

For more than ten years the Petroleum Industry has used and benefited from a Reliability Information and Failure Tracking System for electrical submersible pumping (ESP-RIFTS). More recently another RIFTS system for progressing cavity pumping (PCP-RIFTS) has proven to be beneficial to participating members. At the 2010 Sucker Rod Pumping Workshop, discussion started about developing a RIFTS project for sucker rod pumping. This is now about to become a reality. The RIFTS systems collect and store information on pumping systems and system failures. This information is tracked to discover different types of failures and failure mechanisms. Companies that are members of the RIFTS Joint Industry Project (JIP) can search this information to determine which system components work best in differing conditions. They can determine which metallurgies or system suppliers are more effective in specific situations. They can benchmark their equipment and processes vs. others.
Participation in the JIP's created for the development of ESP-RIFTS and PCP-RIFTS has been limited to Operating Companies. However, for the Sucker Rod Pumping

Reduction of preventable problems inherent in beam pumping systems can be achieved by continuous monitoring of system loads with electronic equipment and software systems developed by Delta-X Corporation. Electronic monitoring equipment was developed for permanent installation on electric prime mover driven beam pumping units. This equipment provides instantaneous polish rod load versus stroke position data. The equipment's self-monitoring mode allows the pumpoff controller (DXI-30) to interpret polish rod load versus displacement and make a logic decision to shut the well down for a predetermined time when a pumped-off condition is detected. Rod parts and other major downhole problems are also detected and result in setting of an alarm and shutting down the unit until visually inspected and manually restarted. Interfacing capacity is designed into the system to allow plotting load versus position data with a dynamometer or the storing of such data, for later retrieval, in an electronic memory card. These data may be later recalled, using a computer program, to recreate a dynamometer card shape, calculate gearbox torque, and/or a downhole pump card. Introduction of the new DXI-40 microprocessor controller with a communication system allows remote access to all load data. System control can also be effected from a remote location.

QRod is the most widely used program for the design and prediction of the performance of Sucker Rod Beam Pumping Installations. A damped wave equation solution is used to accurately predict the surface dynamometer loads, gearbox torque and pump capacity, with a minimum amount of input. New design tools have been added to include: 1) Slippage Calculator from pump clearances ties the pump efficiency to the predicted pump displacement. 2) Sinker Bar length calculator determines the sinker bar length as pump diameter or pump depth chances. 3) Results can be shown in any system of units. 4) Dynamometer measured surface DYN files can be imported and plotted on top of the predicted dynamometer card. QRod's objective is to help the beam pumping system designer implement state of the art design technology without getting buried with details. Changing a parameter such as tubing anchor, stroke length, stroke rate, or pump diameter is immediately seen in the dynamically updated plots.

The concept of pneumatic actuation of a sucker rod string in a pumping well is not new or revolutionary. There are records of patents and applications dating back to the late 1800"s. These early units did not find wide acceptance due to problems of low efficiency, seal wear and leakage. Also, these early units were restricted in depth capacity to about 4000 feet maximum in most cases. There are surface pneumatic pumping units available today that overcome the problems of lew efficiency and seal failure by using new concepts in system control and entirely new seal materials and seal technology. This paper deals with the system design and field application of the most popular of the new generation of pneumatic oilwell pumping units. Applications discussed range from dewatering 1000ft gas wells at 3 BPD to pumping 10,000~ft oil wells at 200 BPD.

ConocoPhillips San Juan Business Unit rod pumps more than 50 "S" shaped deviated wells. The load a sucker rod applies to the tubing wall is called sideload. Sideloads will be higher in the depth intervals of the tubing that are more deviated. The time requred to wear the sucker rod or tubing to failure should be a function of sideload. ConocoPhillips San Juan's "S" shaped rod pumped wells have shallow curved sextions that tend to have sideloads of one hundred pounds or greater, and many have been running for several years. ConocoPhillips presents sideload vs. running time data for their longer running wells, and learnings from two "S" well repairs completed in early 2012.

The oil and gas production organizations have used the service factors applied to sucker rod string allowable loads and stresses for many years. However, many have used the service factor described in API RP 11BR1 only to reduce the maximum allowable stress since they are operating in corrosive service. This paper will discuss the development of the service factors and provide recommendations not limiting the rod loading by using a derating factor.

Paraffin Accumulation in the tubing of pumping oil wells has been a costly problem since the beginning of the oil industry. Some fields have a severe paraffin problem while others do not have enough paraffin accumulation to ever restrict the production of the wells. Each field has a different paraffin problem all its own. The accepted use of sucker rod type paraffin scrapers to remove paraffin from pumping oil wells is relatively new to the industry. Sucker rod type paraffin scrapers became popular between 1946 and 1950.

Two new developments are eliminating costly sucker rod pin failures. The first is the undercut or stress relieved pin which eliminates the critical point where all fatigue failures occur. The second is the thread rolling process which improves the fatigue resistance of the thread.

I am not going to announce a new break through to end all POC failures. If you want to hear God laugh, tell him about your new 10-year plan or solution to end all lightning damage. My goal today is to show some incremental steps we have taken to reduce costs and improve reliability. This is a preliminary report. This is not mature technology tested with a large number of devices through many storm seasons. Some background is needed for perspective.