Production Logging - RMP Blended

DISCIPLINE: Production & Completions / Reservoir Engineering
 
LEVEL: Intermediate
 

DURATION: Approximately 50 hours self-paced or recorded instructor-led activities

INSTRUCTORS: Dr. Dale Fitz

TUITION: $4,410 USD
 
 
 
 

ABOUT THE COURSE: Production logging refers to acquiring a suite of logging measurements in a completed well that is either on injection or production to evaluate the flow performance of the well or the reservoir. Special purpose production logging instruments can evaluate the well completion or look behind the pipe to evaluate the formation and its fluids in the near-well bore vicinity. Production logs are playing an increasing role in modern reservoir management by providing the only means of directly identifying downhole fluid movement. This course will cover single-phase and multi-phase fluid flow in pipes, the theoretical bases of production logging techniques, production log interpretation, and operational considerations in acquiring production logs. Numerous field examples are used to illustrate the principles of production log interpretation.

DESIGNED FOR: Petroleum and drilling engineers and managers, reservoir engineers, subsurface engineers, production engineers/technologists, petrophysicists, log analysts, and anyone interested in understanding production logs and cased-hole surveys.

Course Dates & Options:

On-Demand      ENROLL NOW 

This workshop will be delivered virtually through PetroAcademy™ providing participants with the knowledge they need at their convenience. PetroAcademy™ FAQ

This course is made up of the following skill modules 

  • Conventional Production Logging: Temperature & Single-Element Spinners
  • Conventional Production Logging: Two-Phase Flow
  • Production Logging in High-Angle/Horizontal Wells
  • Advanced Nuclear Production Logging
  • Special Purpose Production Logging

The goal of production logging is to obtain an accurate interpretation of downhole tool measurements of temperature, pressure, fluid holdups, and fluid velocities to determine flow rates of each phase. Achieving this goal requires understanding the measurements made by various production logging tools and how these tools make those measurements. This module focuses on interpretation of single-phase flow. It covers temperature logs and single-element spinner-type flow meters and how to use them to determine flow rates for single-phase flow.


You will learn:

  • How to identify fluid entries on a temperature log run in a flowing well and how to distinguish gas entries from liquid entries due to the Joule-Thompson cooling response
  • How formation thermal conductivity affects the shape of the geothermal gradient
  • How formation thermal diffusivity affects the rate of wellbore warm back when shutting in a flowing or injecting well
  • How to calculate relative flow rates from a flowing temperature log
  • How fluid heat capacity affects the shape of a flowing or an injecting temperature log
  • How to identify injection intervals on an injecting temperature log and how to calculate their relative injection rates using the Ramey equation
  • The different types of spinner flow meter tools and how they make their measurements
  • How to identify fluid entry/fluid injection rates on flowing/injecting spinner surveys
  • How to calculate flow rates from a multiple-pass spinner logging survey

The goal of production logging is to obtain an accurate interpretation of downhole tool measurements of temperature, pressure, fluid holdups, and fluid velocities to determine flow rates of each phase. These measurements provide the only way to know for sure what is happening downhole. Achieving this goal requires understanding the measurements made by various production logging tools and how these tools make those measurements. This module focuses on interpretation of two-phase flow. It covers pressure, differential pressure, capacitance, focused gamma fluid density, non-focused gamma, and backscattered gamma holdup measurements, the definition and description of two-phase flow regimes, and how to use them to determine flow rates for two-phase flow.


You will learn how to:

  • Identify fluid entries on pressure, differential pressure, capacitance, focused gamma density, non-focused density, and backscattered gamma logs acquired in a flowing well and how to calculate fluid holdups from these measurements.
  • Understand which measurements can be used in deviated and high angle-horizontal wells and how to interpret those measurements that can be used in these conditions.
  • Recognize which measurements are preferred for gas holdup, oil holdup, and water holdup.
  • Indentify basic flow regimes for two-phase flow and how to estimate when each might be occurring down hole.
  • Recognize how two-phase flow affects a spinner log, how to correct for it when this can be done, and when one needs measurements in addition to the conventional spinner measurements.
  • Calculate two-phase flow rates from a multiple-pass spinner logging survey using one or more types of fluid holdup measurements when fluids are well mixed.

 

The goal of production logging is to obtain an accurate interpretation of downhole tool measurements of temperature, pressure, fluid holdups, and fluid velocities to determine flow rates of each phase. These measurements provide the only way to know for sure what is happening downhole. This module focuses on interpretation of multiple-phase flow in high-angle to horizontal wells. Basic flow regime principles are reviewed and the effects on flow regime due to increasing well deviation are discussed. Because high-angle flow tends to be stratified in most cases, array logging tools that make multiple measurements across the wellbore profile are introduced. Two basic approaches for calculating multiple-phase flow rates in high-angle wells are presented.


You will learn:

  • How increasing wellbore deviation increases slip velocity and heavier phase fluid holdup as well deviation increases to 90°
  • Why center-weighted production logging measurements are not suitable for calculating fluid holdup and flow rates in high-angle to horizontal wells
  • How gas holdup optical probes, water holdup resistance probes, and multiple-phase holdup capacitance probes work
  • How array mini-spinners work
  • How to calculate two-phase flow rates from a single-pass logging program using multiple holdup and spinner array measurements

The goal of production logging is to obtain an accurate interpretation of downhole tool measurements of temperature, pressure, fluid holdups, and fluid velocities to determine flow rates of each phase. These measurements provide the only way to know for sure what is happening down hole. This module focuses on interpretation of multiple-phase flow in vertical to high angle and horizontal wells using advanced nuclear production logging techniques. Pulsed neutron capture, pulsed neutron spectroscopy, and oxygen activation measurement principles are reviewed with emphasis on those measurements that have production logging applications. Unlike conventional and array production logging measurements that can only sense what is happening inside the casing, nuclear measurements can also sense some of what is happening behind the casing.


You will learn:

  • How pulsed neutron capture, pulsed neutron spectroscopy, and oxygen activation tools work.
  • How to identify formation and borehole fluid contacts and distinguish between the two.
  • Which measurements are used to identify formation properties versus completion effects.
  • How to use a pulsed neutron capture tool to log down and identify hydrocarbon/water contacts in the casing and annulus with the well shut-in.
  • How to interpret data and estimate flow rates from oxygen activation measurements.
  • How to use a pulsed neutron capture tool with gadolinium tracers to estimate oil and water flow rates.
  • How to determine gas and oil holdup from pulsed neutron spectroscopy measurements.

 

 

This module covers the measurement principles of three types of special purpose production logging instruments: noise logs, radioactive tracer surveys, and fiberoptic temperature measurements. Upon completion of this module one should know how to run and interpret a conventional noise logging tool, plan, run, and interpret data from a radioactive tracer survey, and use data in conjunction with well production data to interpret fiber optic temperature measurements. One should also know how to design and execute a complete cased-hole and production logging program for a given well.

You will learn how to:

  • Describe how a noise tool is designed and how it operates.
  • Understand how different flow regimes affect the frequency content of a noise log and be able to identify some of these from a conventional noise log.
  • Explain how a spectral noise tool operates and describe how it is different from a conventional noise logging tool.
  • Describe how radioactive tracers are used.
  • Determine injection rates from slug tracking and velocity shot radioactive tracer surveys.
  • Understand how fiberoptic temperature measurements are made and explain the difference between these types of temperature measurements and conventional temperature logging tools.
  • Use time-lapse fiber optic temperature data with detailed production data to locate water entries in a flowing oil well.
  • Use the principles of designed a logging program to plan and design a complete cased-hole and production logging program for a complex well