In all successful tubular management programs NDT is used to know the real condition of pipe proposed for projects and to gain knowledge of used tubing at the well site. There are several testing methods available such as electromagnetic, ultrasonic, magnetic partible, eddy current and gamma-ray applied to various testing apparatus. There is an assumption made every day about new tubular production are defect free so know your material and its source, inspected until a failure occurs. in many mays nondestructive testing is applied to help show the condition  of new tubular products and to provide guidance on used tubing while pulling and in facilities for reclamation. NDT is directly associated to positive economics through extending the mean time between failures.

Hydrofacturing with 100% recycled water is very desirable in highly sensitive clay formations to mitigate swelling and production impairment. Recycling of produced water can also save operators thousands of dollars per well in fresh water, Trucking, and disposal costs. Yet one obstacle to reuse for many produced waters in the Permian Basin is high hydrogen sulfide (H2S) concentrations.

With typical H2S treatments, such as scavengers, chemical and biological oxidation, the cost/bbl is prohibitive on produced water and high H2S levels. A new, more economical H2S remediation techniques addresses such challenges safely and economically. The water is then clarified, creating a low total suspended solids (TSS) solution ready for hydrofractuing.

This paper discusses the treatment of 22,000 bbl of high H2S produced water used in the successful completion of an 8-stage continuous slickwater frac in the Ramsey Formation, of the Black River South Field, in Eddy County, NM.

Tank lining failures are not an uncommon occurrence in the oilfield.  Sometimes we chalk it up to bad luck, poor application, lying paint salesmen, or just bad coating.  But isn't there some science and testing behind tank lining formulations?  This paper will describe some of the testing procedures for qualifying tank linings and the science behind them.  There will also be some discussion about how failures seen in the lab correlate to failures in the field.

Tank lining failures are not an uncommon occurrence in the oilfield.  Sometimes we chalk it up to bad luck, poor application, lying paint salesmen, or just bad coating.  But isn't there some science and testing behind tank lining formulations?  This paper will describe some of the testing procedures for qualifying tank linings and the science behind them.  There will also be some discussion about how failures seen in the lab correlate to failures in the field.

During recent discussions with operating company field and engineering personnel, it was discovered that some companies may not have a failure tracking process nor know the benefits of establishing one. 

This paper will provide a summary of prior published industry efforts and include three (3) separate failure reduction studies showing the benefits of failure tracking ranging from over 17 years to a few months of operation.  These studies from three (3) different operators in the Permian Basin showed the benefits of: determining what downhole equipment failed and the cause of the failure, tracking the failure location in the well, and calculating the final reduction in operating costs due to reduced failures and reduced workovers. This paper will also show the additional benefits from keeping good records and knowing the manufacturer of the downhole equipment and/or if the downhole equipment manufacturer was changed.

Analysis and control of reciprocating rod lifted (RRL) wells has changed drastically over the past 20 years.  Advanced diagnostic tools first started appearing on desktop applications, and over time have shifted to the wellsite to provide more accurate control of an RRL system in real-time.  All of these tools depend on a dynamometer card in order to properly analyze and control an RRL system.  However, the inputs to the dynamometer card are often of questionably accuracy.  A poor quality dynamometer card can lead to improper control of the RRL system and inaccurate results from the calculations that depend on the dynamometer data (i.e. rod stress, gearbox torque, structure loading, PIP, etc.).  This paper will discuss the variety of instruments used to capture the inputs to a dynamometer card (polished rod load and position), their strengths and weaknesses, how to recognize errors in the input data, and how to correct it.

Pumps are the heart of a rod pump system, but as operators, how much do you know about the pumps that are being run into your wells and how they are being repaired.  This paper will briefly describe pump repair procedures, best practices that the shop should be following, and a pump shop inspection report that helps identify if those procedures are being followed. It will cover what pump failure data should be captured, why it is important, and what type of information may be available in report form. Many operators do not realize that you can gain valuable well and operational data from a pump report besides what is needed to optimize the pump alone. It will also explain how the operator should get involved in the decisions that affect the pump design and repair which can affect costs and run life.  

Fluid Extraction Technology can improve down hole gas separation by employing material and fluid flow properties in ways that are not now effectively utilized.  Downhole pumps that handle fluids are adversely affected by free and entrained gas entering the inlet of the pump.  To separate the gas ahead of the suction of pumps in the bottom of a well, operators typically configure a path for the fluid to be redirected downward to allow the gas to rise while the liquid falls to the intake of the pump.  Virtually all of the gas separators use single pass serial separators based on gravity.  The primary separation is typically the tubing by casing annulus and the second stage of separation is the labyrinth of falling liquid and rising gas inside the mud anchor or packer assembly.  This technology can be very effective but often times is not sufficient.  In addition, the size and length of the equipment has a larger material footprint than necessary.

Fluid Extraction technology uses gravity but also uses mechanical and fluid properties to enhance separation.  These attributes include wettability, fluid adhesion, gas nucleation and the concept of Liquid hold up or circulation cells.  Integrating these concepts allows better use of the primary flow volume of the casing by tubing annulus.

The full potential and benefits of the fiberglass sucker rod (FSR) are not being realized.  FSR manufacturers are toned to meet the requirements for increased operating ranges and one-time pull loads of FSR.  Increasing the operating load requires the redesign of the end fitting to ensure reliability.  This paper outlines the standard design of an end fitting and how it interfaces with the pulltruded fiberglass rod. The test data used to validate the design is also included.  The overall wedge design is explained in detail, demonstrating the interaction of forces acting on the rod/end fitting interface. The stress range diagram will be presented with emphasis on the critical areas of the end fitting design. The overall goal is to show how fiberglass is stronger than steel.

A companion paper is being made to show the graphical analyses for the wells that Sandia measured surface and downhole loads at various depths with a special downhole load cell.

This paper will provide an analysis of the operating conditions that were occurring that resulted in these downhole dynagraphs. Additionally, these operating conditions will then be entered in three available industry rod string design programs that include: QRod, SRod and RodStar to see how accurately these design programs predicted the actual, measured loads.

Improved rod tongs have recently been introduced for rod connection make-up and break-out in the field, with the purpose of reducing sucker rod failure rates. This paper will compare one of these tongs to the present industry standard sucker rod tong, comparing and contrasting each tong’s capabilities, advantages, drawbacks, and effect on rod string performance in the wellbore. In addition, basic job time studies, best practices, and suggested well selection criteria will be discussed.

Sucker rod pumping applications are the oldest and most widely used means of artificial lift for oil wells. The pumping performance and the longevity of the pumping systems with their corresponding pump parts have improved significantly throughout the years, but the failures remain inevitable. These failures are costly and time consuming for operators, but analyzing those enables us to improve the part design and the decision process of part selection for certain well conditions, and minimize future failures.

This paper focuses on pump barrel selection and operation with regards to base metallurgies coupled with various plating processes. It aims to inform the reader of common pump barrel failures and their causes, along with educating operators about available barrel types and their optimum operating environments.

The benefits of the Beam Gas Compressor® for rod pumped wells has now been modified to a standalone version. Allowing the technology to facilitate a broader range of operations and objectives.  Historically, the Beam Gas Compressor® has been installed on pumping units and utilizes the prime mover of the pumping unit to drive a piston inside a proprietary designed cylinder. This paper describes how this technology has been adapted to a standalone compressor installation, how the changes allow more versatile uses and how the technology compares with other types of compression.

Typical production profiles using a decline curve are then used with IPR equations to predict IPR expressions with time into the future.  Then using application rules such as limiting depths and rates, gas separator feasibility for pumps and flowing well and gaslift calculations from Nodal programs, Artificial Lift possibilities are mapped out into the future.  The techniques are not limited to the production profiles used as an example. 

Wireless high-frequency motor power-current-voltage measurements are used to analyze the electrical and mechanical performance of pumping units.  The sensors can be mounted permanently in the electrical box with a water-tight connection on the side of the electrical box for attachment of a small plug-in radio for wireless communication to a PC base station.  These measurements can be performed without opening the electrical box.  In addition, starter boxes without internal sensors can be analyzed using portable sensors that require opening the box and attachment of two current and three voltage sensors.

TAM Software in the PC receives and analyzes the data to determine power usage, power generation, pumping unit balance, gear box upstroke and downstroke torques, motor loadings, and power line loss.   Power line loss is an analysis performed to analyze the power line loss between the electrical system and the pumping unit motor.  The counter-weight movement for gear box balance is determined easily without use or knowledge of the pumping unit dimensions. 

Many operators in the Permian Basin have moved from drilling vertically to developing leases with horizontal drilling.  After implementing a horizontal drilling program, three critical challenges emerge:  1) selecting the most efficient means of initial production; 2) using a rod pump design without experiencing gas interference or losses in volumes; and 3) handling a horizontal well at pumped-off conditions.  Drawing the well down as quickly as possible is ideal for generating the best economics. The initial investment and operating costs of the artificial lift system must also be considered when performing economic analysis.  Rod pumping horizontal wells to produce the high rates that the model describes is challenged by gas interference which has resulted in the following: rod and tubing wear, upper buckling tendencies, increased man hours trying to resolve problems, and a loss in production.  When pumped off conditions occur while rod pumping from the kick off point, a noticeable decline in production can be observed.  In low pressure reservoirs, lowering the pump into the curve can prove to restore or even increase production rates.  By studying past cases of producing Yeso horizontal wells in the New Mexico Shelf Platform, COG has been able to select an optimally sized ESP, smoothly convert to a rod pumping system to achieve pumped off conditions, and continue to produce in the curve to avoid losses in production.

When using artificial lift, namely sucker rod pumps, there are three major factors to consider when trying to control and optimize production: elasticity, viscous friction and mechanical friction. The Modified Everitt-Jennings uses an iteration on dual damping factors to approximate the correct amount of viscous friction to be removed to mimic the energy lost through the viscous forces imparted on the outer diameter of the rods by the fluids. A precise Fluid Load Line Calculation provides a concavity test to diagnose the presence of mechanical friction.

Secondly, in order to maximize production and prevent rod string damage, pump-off control technology must be used in conjunction with sucker rod pump installation. The most accurate type of pump-off control is one using pump fillage. The Modified Everitt-Jennings combines an in-depth stress analysis with a powerful Pump Fillage Calculation, which outputs correct pump fillage regardless of downhole conditions present.

In this paper, a complete methodology for controlling sucker rod pumps is presented. This methodology combines state of the art, innovative methods that smartly and efficiently automate the control of sucker rod pumped wells.

In the case of a vertical well, the rod string can be compared to an ideal slender bar. Therefore the propagation of stress waves occurring from cyclic loading and un-loading during a pumping cycle becomes a one dimensional phenomenon.

The most accurate way of computing downhole data, is therefore by solving the one-dimensional damped wave equation. The Modified Everitt-Jennings algorithm combines finite differences with other state of the art innovative algorithms to provide precise downhole data, accurately reflecting present downhole conditions.

In the 1990’s, Sandia National Laboratories were contracted to measure actual position and load data at different depths of the rod string through a series of downhole tools.

In this paper, results from the Modified Everitt-Jennings methodology are compared to actual field measurements, captured by the Sandia National Laboratory experiment.

The Electronic Downhole Load Cells (DHLC) was used during the mid-1990s to acquire downhole dynamometer data.  The unique DHLC was mounted at a desired location in the rod string (usually between two rod tapers).  Dynamometer data was collected while the well operated.  SANDIA coordinated collecting DHLC data on six (6) different types of wells.  The petroleum industry provided wells and SANDIA collected, de-coded and presented the data.  NABLA and others concurrently acquired the surface Dynamometer measurements.  DownDYN software developed by SANDIA was used to display and export the collected data.

The dynamometer data acquired at each rod taper for each well will be displayed.  The DownDYN software is no longer supported by current Windows Operating system.  This valuable information will be lost, if the DownDYN software is not modernized.  Downhole Load Cell data measured at the pump resolved the display of the downhole pump loads. This paperwill discuss the true/effective load argument for display of downhole dynamometer data.  

A new term “Equivalent Gas Free Pump Fillage Line” represents the amount of liquid fillage inside the pump chamber when the traveling valve opens during the down stroke.  Adjustments for gas in solution, slippage, free gas, and compressibility of liquid due to pressure and temperature are required to determine the amount of stock tank liquid produced per day for a selected stroke.

Field dynamometer data from eight different wells will be used to compare the calculated to measured surface oil and water production volumes.   Equivalent gas free pump fillage line will be shown for each well’s representative pump card.

The pump card calculated gas produced up the tubing and the acoustic fluid level tested free gas produced up the tubing/casing annulus are used to determine system gas separation efficiency.  This enhanced analysis technique allows answering many complicated questions concerning oil, water, and gas production with respect to the downhole pump card.

We explore how minor modifications in routine usage of typical rod pumping equipment may improve the performance of rod pumped wells; e.g. how initial proper selection and implementation of polished rods and can limit well failures.  Also discussed are pump design changes to mitigate common pumping problems, and why standardized pump designs are not over-all beneficial to producing wells.  Additionally, we illustrate that standardized or “common” downhole design limits production rates

This paper will highlight the use of high liquid volume plunger lift to date in the Southern Delaware Basin.  This method of lift was first considered by COG Operating, LLC in an effort to bridge the gap for taking a well from flowing to rod pump.  Historically in the Southern Delaware Basin this was accomplished with high cost electric submersible pumps.  One of the criteria for success was that plunger lift would be able to replace the electric submersible pumps and economically maintain the well on its natural decline.   To date, COG has eight wells that have been successfully operating with high volume plunger lift. Representative decline curves will be presented, along with operating pressures and histories on the successful wells in the project.  The paper will be presented both from the prospective of the operator and then operating criteria from the vendor that have made this project a success.

Knowledge of the magnitude of different components of mechanical torque acting on the gearbox is crucial for the design and analysis of sucker-rod pumping installations. Gearbox torques include the torque required to drive the polished rod and the torque used to rotate the counterweights. In addition to these, inertial torques arise in those parts of the pumping unit that turn at varying speeds. As shown in the paper, all torque components are functions of the crank angle, consequently their exact calculation necessitates the knowledge of the crank angle vs. time function. This circumstance, however, complicates torque calculations because contemporary dynamometers, used to acquire the necessary operating data, do not provide any information on the variation of the crank angle during the pumping cycle. The paper introduces a solution of the problem and presents an iterative calculation of the crank angle vs. time function from dynamometer data. Based on this function crank velocity, acceleration, as well as beam acceleration are easily found and all necessary gearbox torques can be evaluated. The paper describes the details of the developed calculation model and presents example calculations.

The early detection of "sweet spots" for oil/gas well site selection and fracturing in shale reservoirs is a challenge for many operators. Most of the time, unique parameters are utilized (i.e. brittleness based on geomechanical and geochemical parameters) to determine the "sweet spots" for well site placement. Additionally, the fractures are generally placed equidistantly. 

This may create short transverse and/or non-planar hydraulic fractures that are problematic during hydraulic fracturing and may create suboptimal production.

This technology utilizes an integrated approach to site selection and fracture sequencing that allows for the optimal productivity of the well. 

This integrated approach utilizes both petrophysics and geomechanical data to develop a Fracturability Index to guide well site selection and fracture positioning in unconventional shale plays. It also, introduces an optimization approach based on mathematical formulations to guide scheduling of fracturing operations in big resources.

In the hydraulic fracturing industry, it has been a long-time problem and struggle to accurately track the usage of chemicals on fracturing site and make proper management decisions.  The manual approach has measurement error and the chemical inventory information cannot be accessed by people such as directors or managers who may not be on site but need the critical information for decision-making. Obtaining chemical inventory information automatically and making it available on-line would significantly save material costs, enhancing asset management efficiency. In a designed system, a guided-wave radar level sensor is used to measure the chemical level and the chemical inventory data are updated on an internet server through the satellite internet in the control van, making the information available on-line for engineers, managers and clients. The proposed monitoring and inventory system will greatly enhance asset management efficiency and reduce cost for the oil and gas industry.