2015 Gas Well Deliquification Workshop
Technical Presentations
Session: I --- New Technologies,
Session Chair:
Challenges, General Topics
Chandran Peringod
Bill Lane
Presentation Title: I – 1
Company(ies):
Vertical Well Production Recovery in Bonanza Creek Energy, Inc.
a Horizontal Well Development Field
‘A Strategy of Compression, Plungers, Swabbing, Hybrid Gas Lift Installations and Pumping Units’
Author(s):
Dawn Lima
Abstract:
Contact Information:
DLima@bonanzacrk.com
The DJ Basin is a historic Oil & Gas play with >10,000 producing vertical wells, with varying GORs. As Operators
have shifted their development strategies from vertical to horizontal drilling programs, in some areas the vertical production volumes have decreased.
The main cause of production loss is higher wellhead pressure caused by higher line pressure due to increased gas
volume in the gathering system. Another challenge for Production Engineers is communication between new horizontal wells and older vertical wells. Production from vertical wells can become significantly suppressed, thus requiring a strategy to return these wells to pre-existing levels.
This presentation will step through the strategy that Bonanza Creek utilized to return to production fifty five low GOR
vertical wells that were suppressed due to horizontal well development. This strategy included facilities upgrades,
hybrid gas lift, plungers, and pumping unit installations.
Notes:
2015 Gas Well Deliquification Workshop
Page 2
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: I --- New Technologies,
Session Chair:
Challenges, General Topics
Chandran Peringod
Bill Lane
Presentation Title: I – 2
Company(ies):
Lab Testing of Inexpensive Artificial C-FER Technologies
Lift Systems for Shallow Gas Well
Cenovus Energy
Deliquification
Author(s):
Contact Information:
Daniel Booy
d.booy@cfertech.com
Kelly Piers
Cindy Wolfe
Abstract:
Due to low gas prices, operators have had a difficult time economically removing unwanted liquids from shallow gas
wells. In response to this, a group of operators and the Petroleum Technology Alliance Canada (PTAC) came together and created the “Shallow Gas Dewatering Pump Project” to investigate new, novel and inexpensive artificial
lift technologies to remove these unwanted liquids. C-FER Technologies acted as the technology service provider for
the project.
After reviewing submissions of novel artificial lift systems from almost 20 vendors, seven of the vendors were selected for further testing. A custom “flow loop” was then designed and built at C-FER to replicate a variety of shallow gas
well conditions so that full scale tests of these systems could be completed. The loop was designed and constructed
so it was modular, so that each system could easily be installed and removed from the flow loop, that it could handle
a variety of test fluids (water, air, water/solids mixture), and that the pump could be seen by the operators during testing.
Although two of the vendors decided to withdraw their systems from the test program, five systems were tested, including a jet pump, a hydraulically powered piston pump, an air chamber pump, an electric submersible progressing
cavity pump, and a rod pump. Testing included performance curve tests with varying intake and discharge pressures, testing operation in a pumped-off state (with air entering the pump inlet), and operating with a water/solids
mixture as the test fluid.
A brief summary describing the formulation of the consortium, the unique artificial lift systems that applied to the consortium for testing, construction of the flow loop, the systems tested, some possible pros and cons of the systems
tested, and how the project moved forward with additional field testing is described .
Notes:
2015 Gas Well Deliquification Workshop
Page 3
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: I --- New Technologies,
Session Chair:
Challenges, General Topics
Chandran Peringod
Bill Lane
Presentation Title: I – 3
Company(ies):
Hygr Fluid System Gas Well Deliqui- Hydro Pacific Pumps Inc.
fication
Trident Limited Partnership
C-FER Technologies
Definitive Optimization
Author(s):
Contact Information:
Richard McNichol
dickmcnichol@hydropacificpumps.com
Jeremy Dobra
Daniel Booy
Clint Mason
Abstract:
The Hygr Fluid System is a hydraulically driven pumping system that has been developed over the last five years as
a fluid pumping method for a variety of applications. Not only has the system been tested in water wells and shallow
oil wells, but it has also been applied to the deliquification of gas wells with positive results.
Earlier testing in gas wells for shorter periods of time has shown the dramatic production increases that can happen
when gas wells are deliquified; however, the change in gas production after long-term use of the Hygr Fluid System
was recently investigated during a field trial with Trident Limited Partnership. This operator considered shutting in
one gas well since it was averaging approximately 10% of the expected production level despite regular swabbing,
but instead decided to try installing the Hygr Fluid System. Once the Hygr Fluid System was operating so that the
well was being continuously dewatered, the production not only returned to the expected level but the well is now
producing approximately double the previous production and is far above the projected natural decline rate.
Despite the various system successes, there were some minor issues identified with the system through various field
trials and testing through the “Gas Well Dewatering Pump Project” (a consortium consisting of the Petroleum Technology Alliance Canada and three Canadian operators). However, solutions to these issues were identified that will
result in a more optimized system for future installs.
This presentation will outline the results of 2 ½ years of gas well deliquification and system trials, some of the issues
encountered during this time, and some of the system modifications that will overcome some of the challenges faced.
Notes:
2015 Gas Well Deliquification Workshop
Page 4
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: I --- New Technologies,
Session Chair:
Challenges, General Topics
Chandran Peringod
Bill Lane
Presentation Title: I – 4
Company(ies):
Simulation of Down-Hole Gas Sepa- Echometer Company
rator Performance
Author(s):
Contact Information:
Jim McCoy
lynn@echometer.com
Lynn Rowlan
Abstract:
The performance of down hole gas separators is simulated in software. Different production rates, different sizes of
separators, different SPM and different gas bubble rise velocities are simulated to show the performance of different
separators and different well conditions. This simulation software is a great aid in educating personnel in the operation, performance, selection and proper design of gas separators. Knowledge and use of this software will help operators increase pump fillage and total production and also reduce operating expenses.
Once the pumping/separator system has been defined the simulation starts pump operation and switches to the separator visualization and animation screen, where the user can observe in real time the distribution and flow of the gas
and liquid in the separator. The gas/liquid interface oscillates up and down as the plunger strokes. The user can
start and stop the pump and change the pumping speed so as to observe the effect of SPM on the separator’s performance and the position of the gas bubbles within the separator annulus. The liquid rate that corresponds to a particular condition is displayed in real time and a warning message is shown when the gas breaks through into the bottom of the dip tube and into the pump.
The simulation and visualization software lets the user make adjustments to the separator design in order to develop
the best arrangement for the particular well conditions. Returning to the input the separator parameters can be easily
modified and the new results observed in the animation screen.
The separator simulation application can also be valuable in training of personnel that are involved in monitoring and
optimizing the operation of pumping wells.
Notes:
2015 Gas Well Deliquification Workshop
Page 5
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: I --- New Technologies,
Session Chair:
Challenges, General Topics
Chandran Peringod
Bill Lane
Presentation Title: I – 5
Company(ies):
Why Liquid Loading Occurs, And
Delft University of Technology, The NethHow This Knowledge Helps To Preerlands
vent It
Shell Projects & Technology, The Netherlands
NAM, The Netherlands
Author(s):
Contact Information:
A.T. van Nimwegen
A.T.vanNimwegen@tudelft.nl
L.M. Portela
R.A.W.M. Henkes
G.J. de Vries
Abstract:
Liquid loading is a problem encountered in the production of natural gas, which occurs when the gas velocity in the
production tubing is no longer sufficient to drag the liquid, associated with the gas, upwards. The liquid subsequently
accumulates in the well, exerting a hydrostatic pressure on the reservoir and limiting the production of gas.
When the reservoir pressure is high, and the gas velocity in the tubing is large, and there is relatively regular annular
flow, in which the liquid moves upwards in a liquid film at the wall and in entrained droplets in the gas core. When the
gas velocity becomes low, the flow becomes a much more irregular churn flow, in which the liquid moves upwards in
large, aerated flooding waves and, between the waves, the liquid film is very irregular and moves up- and downwards. The transition between annular flow and churn flow is closely related to liquid loading.
The critical gas velocity, below which liquid loading occurs, is usually predicted by the Turner criterion [1], which
states that liquid loading occurs when the gas is no longer able to drag the largest droplets in the flow upwards. The
calculation of the critical velocity therefore requires an estimate of the size of these largest droplets. However, experiments show that the droplet size estimated by Turner is too large: such large droplets do not occur in the flow.
Using movies made with a high-speed camera, we show that it is the reversal of the liquid film that causes the transition between annular flow and churn flow, and not the reversal of the largest droplets. We also show the complicated
morphology of the gas-liquid interface in the churn flow regime, where many droplets and ligaments are formed. This
morphology causes the large pressure gradient that prevents production of gas in wells.
This improved understanding of why liquid loading occurs can help us in improving the modelling of the onset of liquid loading. But, more importantly, the knowledge that the reversal of the liquid film is the major cause of liquid loading, helps us to develop deliquification techniques. We review two deliquification techniques that change the nature of
the liquid film. Using a hydrophobic coating on the pipe wall, the liquid film is completely removed. By injecting surfactants the liquid film will foam, decreasing the density of the liquid film. Both these techniques decrease the critical
velocity.
The project is funded by NAM, a Dutch subsidiary of Shell and ExxonMobil. The authors would like to thank Kees
Veeken, Ewout Biezen and Ruud Trompert, from NAM, for the valuable discussions.
[1] RG Turner and MG Hubbard. Analysis and prediction of minimum flow rate for the continuous removal of liquids
from gas wells. Journal of Petroleum, 22(11):1475–1482, 1969.
Notes:
2015 Gas Well Deliquification Workshop
Page 6
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: I --- New Technologies,
Session Chair:
Challenges, General Topics
Chandran Peringod
Bill Lane
Presentation Title: I – 6
Company(ies):
Experiments on Gas Well DeliquifiDelft University of Technology, The Nethcation Using Surfactant in Pipes
erlands
with Different Diameters
Shell Projects & Technology, The Netherlands
NAM, The Netherlands
Author(s):
Contact Information:
A.T. van Nimwegen
A.T.vanNimwegen@tudelft.nl
L.M. Portela
R.A.W.M. Henkes1
G.J. de Vries
Abstract:
Liquid loading is a frequently occurring problem when producing gas from wells with a low reservoir pressure. From
experience in the gas industry, it is known that injecting a surfactant (foamer) at the bottom of the well prevents liquid
loading. The surfactant causes the liquid to foam, changing the tubing performance curve and decreasing the critical
velocity required to lift liquids from the well.
In this presentation, we summarise the experiments performed on air-water flow with and without surfactants in vertical pipes at atmospheric conditions. In these experiments, we use a high-speed camera to make observations of the
flow morphology and we measure the pressure gradient and the liquid holdup. To increase our understanding of deliquification using surfactants, we study the effect of the surfactant concentration and the pipe diameter on the performance of the surfactant.
For air-water flow at large flow rates, there exists a relatively regular annular flow with a liquid film at the wall and
droplets at the gas core. At low gas flow rates the liquid film reverses, leading to an irregular churn flow. The transition between annular flow and churn flow is associated with the onset of liquid loading.
At large gas flow rates, the surfactants cause the formation of foam waves on the liquid film. These waves lead to a
larger interfacial friction between the air and the liquid film, and therefore to a larger pressure gradient. This effect is
stronger at smaller diameters.
At low gas flow rates, the lower density of the foam makes it easier for the gas to drag the liquid upwards. Therefore,
the morphology of the flow becomes much more regular, and the pressure gradient and the liquid holdup decrease.
However, adding a large amount of surfactant leads to the formation of a very thick foam film, which causes a large
interfacial friction and a large pressure gradient. There exists an optimum surfactant concentration for reducing the
pressure gradient. This optimum concentration increases with decreasing gas flow rate, increasing liquid flow rate
and increasing pipe diameter.
The project is funded by NAM, a Dutch subsidiary of Shell and ExxonMobil. The authors would like to thank Kees
Veeken, Ewout Biezen and Ruud Trompert, from NAM, for the valuable discussions.
Notes:
2015 Gas Well Deliquification Workshop
Page 7
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: II --- Reservoir, Stimulation, Session Chair:
Impact of Loading
Rob Sutton
Wayne Hill
Presentation Title: II – 1
Company(ies):
More Than Drops –Analysis of LiqBP – US Lower 48 Onshore
uid Film on Tubing and Implications Blackstone Instruments, Inc.
for Loading
Author(s):
Contact Information:
Justice Diven
justice.diven@bp.com
John Bowman
Tom Lovell
Randy Koenig
Wayne Hill
Abstract:
BP and Blackstone Instruments Inc. have been developing a gas well model for intermittent flowing wells. The modelling work has involved investigating the role of liquid film thickness on the tubing wall and its role in liquid loading.
The presentation will share analytical observations about liquid loading via this mechanism and compare it with the
traditional understanding proposed by Turner et al.
Potential implications for liquid loading and unloading will also be discussed.
Notes:
2015 Gas Well Deliquification Workshop
Page 8
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: II --- Reservoir, StimulaSession Chair:
tion, Impact of Loading
Rob Sutton
Wayne Hill
Presentation Title: II – 2
Company(ies):
Flow Assurance Principles Applied
Consultant
to Unconventional Gas Well Deliqui- Marathon Oil Corporation
fication
U of Tulsa
Author(s):
Contact Information:
Robert P. Sutton
suttonr@sbcglobal.net
Steve Pohler
Dr. Cem Sarica
Abstract:
The lateral section in the horizontal wells used to develop unconventional reservoirs is analogous to a surface flowline. In the case to the well, the lateral reaches out into the reservoir a mile or more to access reserves and deliver
production to the well. At the surface, flow assurance disciplines are employed to ensure adequate performance of a
flowline/pipeline. It is only logical that these principles be applied to the downhole horizontal lateral.
Many operators are drilling toe up laterals. One thought behind this is the water will drain to the heal where it can be
pumped from the well. The resulting multiphase flow scenario results in a situation where undersaturated natural gas
in contact with water in the lateral can result in significant vaporization of the free water. The resulting concentrated
salts can result in salt/scale deposits that could block the lateral. Traps along the lateral are a likely location for this
to occur. Most of the wells have multiple traps along the lateral and the fraction of the lateral beyond the first trap
from the heal can be significant. Given the projected long life of the well and the need to operate at low bottomhole
pressure, a flow assurance problem results requiring more than a simple deliquification strategy.
Notes:
2015 Gas Well Deliquification Workshop
Page 9
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: II --- Reservoir, StimulaSession Chair:
tion, Impact of Loading
Rob Sutton
Wayne Hill
Presentation Title: II – 3
Company(ies):
Gas Slugging in a Horizontal Well
Franklin Electric Co. Inc.
Fitted with an ESPCP
Author(s):
Contact Information:
Don Brown
dbrown@fele.com
Russell Bookout
Abstract:
Two ESPCP (Electric Submersible Progressing Cavity Pump) systems were installed in horizontal gas wells in the
Fayetteville Shale basin. The experiences in one of these wells will be detailed. The initial installation encountered
significant issues related to gas slugging that eventually shortened the life of the pump. After the failure of this initial
system, two subsequent installations occurred in this well. In each installation, the equipment and conditions were
changed in an attempt to increase the life of the ESPCP. The current installation has been successfully operating for
over 6 months. The issues faced and the solutions developed will be discussed.
Notes:
2015 Gas Well Deliquification Workshop
Page 10
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: III --- Compression, GasSession Chair:
Lift, Velocity String
Larry Harms
Mike Rost
Presentation Title: III – 1
Company(ies):
Methods for Improving Gas Lift Effi- Weatherford Production Optimization Sysciency in Large Systems
tems
Author(s):
Contact Information:
Ross Moffett
Ross.Moffett@Weatherford.com
Abstract:
Gas lift systems often suffer from consistent ailments that may be remedied by automated solutions in order to increase production and cost efficiency. At the beginning of the gas lift phase, during unloading, gas is often over injected in order to expedite the production phase. This often damages the gas lift valves, but may be remedied by
using automated control of the unloading phase.
Often every well has its own gas lift compressor even on multi-well pads. With automation, a couple of large compressors may be shared among several wells. Gas lift gas is sometimes in short supply due to high fluid ratios,
which can be accommodated with hosted analysis workbench systems that adjust rates to optimal every day. When
a shared compression source is lost or diminished, all wells will normally load up and ultimately fail in a way that requires manual intervention.
With a central automated controller, high-producing wells may be prioritized for whatever supply is available and
failed wells brought back online automatically when gas supply returns. This saves operators from spending many
hours re-starting wells after fixing a failed compressor in the middle of the night.
Notes:
2015 Gas Well Deliquification Workshop
Page 11
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: III --- Compression, GasSession Chair:
Lift, Velocity String
Larry Harms
Mike Rost
Presentation Title: III – 2
Company(ies):
A Novel Approach for Cost Effective Caltec, U.K.
Revival of Liquid Loaded Wells
Author(s):
Contact Information:
Sacha Sarshar
C.Mansfield@caltec.com
N. Beg
Abstract:
The causes of liquid loading are generally well understood by the industry. Finding the most cost effective solution to
de-liquify such wells is however a challenge as no guideline or software is available to assist the operators in their
selection process. In some cases, past experience for revival of wells within the same field may help to decide on the
most cost effective solution, but all wells may not perform in a similar manner in compartmentalised reservoirs.
A relatively simple technique is to test the well at a lower flowing wellhead pressure (FWHP) (which is below the
manifold pressure), and establish the minimum FWHP which can de-liquify the well or enables the well to produce in
a stable manner. Typically the facilities are constrained to operate at the pressure dictated by the downstream manifold and pipeline pressure, and cannot generally operate at pressures below the manifold pressure. A well test system may be used, but may result in flaring of production if the produced fluids cannot be re-pressurised for reinjection
to process system. In many cases, there is no test separator available to carry out such tests.
This paper describes the features of a solution involving a surface jet pump (SJP) and/ or a test separator with a
booster pump for the liquids, enabling the separator to operate for extended periods (or permanently) at pressures
below the manifold pressure. In the absence of a conventional test separator, a compact cyclonic separator is a good
option. The compact test separator may be able to de-liquify the well without the need for costlier downhole boosting
systems or flaring the produced fluids. The SJP and compact separator are suitable for both offshore and onshore
operations. The paper also refers to the field experience gained by using such a compact well testing and well revival
system. The suggested solutions can also be applied in combination with other downhole de-liquification solutions.
By using the recommended solutions outlined in this paper, considerable savings may be achieved and flaring of
produced fluids avoided.
Notes:
2015 Gas Well Deliquification Workshop
Page 12
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: III --- Compression, GasSession Chair:
Lift, Velocity String
Larry Harms
Mike Rost
Presentation Title: III – 3
Company(ies):
Potential Compressor Story
ConocoPhillips
Author(s):
Larry Harms
Abstract:
Abstract to be provided later.
Notes:
Contact Information:
larry.harms@conocophillips.com
2015 Gas Well Deliquification Workshop
Page 13
2015 Gas Well Deliquification Workshop
Technical Presentations
Session Chair:
Brent Thomas
Kees Veeken
Presentation Title: IV – 1
Company(ies):
Enhancing Gas-Lift Installations by
Patriot Artificial Lift
Utilizing Two Piece Plunger TechSamson Resources
nology
Author(s):
Contact Information:
Stan Lusk
slusk@patriot-lift.com
Eric Perner
Abstract:
Session: IV --- Plunger Lift
Gas Lift is the artificial lift method that most closely resembles the natural flow process of a well and has been utilized
for years in assisting the production of both water and oil. Gas Lift has seen a renaissance over the last ~10 years
with the discovery and exploration of multiple Shale Plays across the country. In a large portion of these plays, Gas
Lift has become the artificial lift method of choice for recovering initial frac water as well as produced water/oil as the
well depletes.
Two-Piece plunger technology is typically utilized in high rate wells that require or benefit from a large number of
plunger cycles per day. Two-piece technology can return a well to as close to a flowing condition as possible while
utilizing plunger lift. Most two-piece applications only require the tubing to be closed for a very short period of time to
allow the plunger to begin its descent.
This presentation will cover the benefits and results of pairing the two technologies together into a Plunger Assisted
Gas Lift hybrid solution. We will discuss where the technology is being deployed and the types of wells along with
benefits seen which can include:
1. Increased production – gas & liquid
2. Reduced injection volumes
3. Paraffin control
Notes:
2015 Gas Well Deliquification Workshop
Page 14
2015 Gas Well Deliquification Workshop
Technical Presentations
Session Chair:
Brent Thomas
Kees Veeken
Presentation Title: IV – 2
Company(ies):
Determination of Plunger PerforEchometer Company
mance versus Well Depth
Session: IV --- Plunger Lift
Author(s):
Lynn Rowlan
Abstract:
Contact Information:
lynn@echometer.com
A new plunger fall velocity model has been developed that predicts a plunger fall velocity in a well at different conditions. This model is based on filed measured plunger fall velocities and laboratory measured fall velocity. The model
uses the Plunger Fall Performance Coefficient, C, to predict the plunger velocity at a different depth, pressure and
temperature. All plungers have the same general trend of fall velocity; where the plunger fall velocity is fast at low
pressure and slow at high pressure. Data acquired from various wells versus depth will be used to compare the
measured fall velocity on a joint-by-joint basis to the predicted fall velocity using the new model. Some construction
features of plungers cause a plunger to fall rapidly, while other features cause the plunger to have a slower fall velocity. A particular plunger’s known fall velocity at a specific pressure and temperature is input into the model and the
model will calculate the fall velocity at all other depths in the well using the well’s pressures and temperature at each
depth.
By accurately knowing the plunger fall velocity, the proper shut-in time for the plunger lift installation can be determined. Use of an acoustic instrument is an effective method to determine a fall velocity during the shut-in time period
for input into the model. When changes to the well cycle impact the operating pressure, this new model can be used
to determine the change in time required for the plunger to fall to bottom during shut-in. Setting the well’s controller
to have the shortest possible shut-in time can maximize oil and gas production from the plunger lift well. Determining
the plunger fall velocity will allow the operator to set the minimum shut-in time for the plunger lift installation. Knowing the plunger fall velocity for specific well conditions will ensure that the plunger will reach the bottom of the tubing
by the end of the shut-in period.
Notes:
2015 Gas Well Deliquification Workshop
Page 15
2015 Gas Well Deliquification Workshop
Technical Presentations
Session Chair:
Brent Thomas
Kees Veeken
Presentation Title: IV – 3
Company(ies):
E-factor: Measuring Plunger Sealing Weatherford
Efficiency
Author(s):
Contact Information:
Manish Agarwal
Manish.Agarwal2@weatherford.com
Abstract:
Session: IV --- Plunger Lift
Plunger lift has been recognized as a major artificial lift system for decades. There are several plunger types and
designs available across the industry. However, operators have not had true measured data to assist in determining
the kind of plunger that best suits the attributes of a well. Over the years, a multitude of plunger designs have been
promoted with various assertions about performance. Unfortunately, most of the designs have little to no physical test
data and there is no way for an operator to distinguish between any given plungers.
One way to test different plungers is to do field testing to measure plunger performance. The challenge with this approach is that each well is different and it’s very difficult to subject different plungers to the same conditions. Hence
the result may not be reliable and the approach requires extensive effort and time.
In this presentation, the author will cover a plunger flow fixture setup which subjects any given plunger to the same
constraints and measures the plunger performance. This performance can be quantified as E-Factor, providing a tool
to the industry to measure and differentiate plunger sealing efficiency. The presentation will cover test data and analysis.
The presentation will also cover how computational fluid dynamics (CFD) modeling can be used for plunger design
improvements. The presentation will cover a plunger CFD model and compare the data obtained between CFD analysis and actual testing.
Notes:
2015 Gas Well Deliquification Workshop
Page 16
2015 Gas Well Deliquification Workshop
Technical Presentations
Session Chair:
Brent Thomas
Kees Veeken
Presentation Title: IV – 4
Company(ies):
Plunger Lift Design for Horizontal
Well Master Corporation
and Deviated Wells
Author(s):
Contact Information:
David Green
David.Green@wellmaster.com
Neil Longfellow
Abstract:
Session: IV --- Plunger Lift
As drilling has steadily trended towards horizontal and directional wells there is an increasing need for knowledge
that allows for optimal operation in these wells. Scientific knowledge surrounding plunger lift has been developed
over several decades for vertical wells and in recent years has become better understood and utilized. However, the
fluid physics in horizontal and deviated wells present new challenges that often cannot be overcome using the conventional knowledge developed in vertical wells. Many of the issues stem from a poor seal and uneven wear experienced by plungers when the tubing angle deviates significantly from vertical.
This presentation seeks to explain how plunger design can overcome these challenges through design philosophy,
computational modeling, experimental testing, and field data. Solid-type and pad-type plungers are addressed,
where the design for solid-type focuses on creating a corkscrew flow structure in which the plunger rotates concentric
to the tubing via the principle of a fluid film bearing, and where the padded plungers utilize the pressure differential
across the tool to create a fluid pressure spring under the pads. Both plunger types benefit from the creation of a
dynamically generated turbulent seal that surrounds the tool and minimizes blow by of gas and liquid.
Conclusions are drawn from relating field and experimental results to theory and computation, giving a practical explanation of why certain design features allow a plunger to excel in non-vertical wells.
Notes:
2015 Gas Well Deliquification Workshop
Page 17
2015 Gas Well Deliquification Workshop
Technical Presentations
Session Chair:
Brent Thomas
Kees Veeken
Presentation Title: IV – 5
Company(ies):
Liquid and Gas Flow Monitoring in
Blackstone Instruments
Plunger Lift
Author(s):
Contact Information:
Wayne Hill
wayne.hill@blackstoneinstruments.com
Nick Lima
John Bowman
Abstract:
Session: IV --- Plunger Lift
Blackstone Instruments is applying its experience with Dynamic Pattern Recognition (DPR) to liquid and
gas production monitoring in natural gas wells. This technique involves analyzing the irregular variation in
the signal from a simple end device to determine the liquid and gas flow conditions. The key challenge in
developing this capability, particularly for liquid production, is obtaining the needed calibration data to
support algorithm development. This presentation describes an interim capability, in which liquid and
plunger arrival are identified using DPR, and the plunger velocity, plunger leakage, and void fraction of
the arriving fluid are estimated using a simple model of plunger lift based on automation data. Results are
provided for both liquid and gas production estimates. When fully developed, this approach should provide a valuable monitoring capability for plunger lift operations.
Notes:
2015 Gas Well Deliquification Workshop
Page 18
2015 Gas Well Deliquification Workshop
Technical Presentations
Session Chair:
Brent Thomas
Kees Veeken
Presentation Title: IV – 6
Company(ies):
Providing an Automated Solution for PCS Ferguson
Running both Plunger Lift and GasLift methods together To Maximize
Well Production
Author(s):
Contact Information:
Peter Piotrowski
mike.rost@doverals.com
Michael Rost
Abstract:
Session: IV --- Plunger Lift
Problem:
Operators are often faced with many challenges when optimizing well production, particularly when choosing an artificial lift method. While maximizing production while reducing CAPEX and OPEX is a constant challenge, sometimes
the best solution to some situations is to combine methods of artificial lift. Combining artificial lift methods is becoming a more common solution for wells that have challenging conditions where one form of lift may not lead to the desired production gains.
Challenge:
When it comes to choosing an artificial lift method, plunger lift and gas-lift are often considered independent lift methods. However, when used in combination on the same site one each method can benefit from the advantages of the
other. Together the two methodologies can take a newly completed well from completion and start of production all
the way to plug and abandon with one solution.
Solution:
This presentation will cover the benefits of combining Plunger and Gas Lift methods on individual wells and or pad
sites. Participants will learn how the main lift method can be assisted by the other lift method. The presentation will
also cover automation used to gain insight into each well and determine the optimal lift method and or combinations
of methods.
Results:
Common problems with one method can typically be solved by the assist of the other method. Although important,
this part of the presentation will focus on issues surrounding the combination of these two lift methods and provide
ideas on work-arounds to solve the most common issues. Q&A time will be provided and audience members encouraged to share their experiences and discuss solutions with the group.
Notes:
2015 Gas Well Deliquification Workshop
Page 19
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: V --- Chemicals --- SelecSession Chair:
tion, Installation, Optimization
Fenfen Huang
Jason Carmichael
Presentation Title: V – 1
Company(ies):
Foamer Technology in a 36” Gas
ENI
Sealine Pliocene Network: A SucBaker Hughes
cessful Case of Liquid Unloading
Author(s):
Contact Information:
Claudio Passucci
Francesco.Pitassi@bakerhughes.com
F. Placca
F. Pitassi
M. Grippo
A. Di Lullo
M. Montini
P. Omarini
Abstract:
The application of surfactant agents, called Foamers, in gas export pipelines can be effective in removing bottlenecks
due to liquid accumulation. These agents mix with the liquids and create a foam that has a lower density than the
original liquids and can be lifted or transported by the produced gas. Therefore, the excessive liquid accumulations
are removed from the pipeline with the effect of reducing hydrostatic loading and frictions. Upon arrival at the receiving facilities, an appropriate defoamer is usually injected to allow for effective gas-liquid separation.
This whole process is usually called “liquid unloading” or “deliquification” and the consequent reduction in pressure
drops often leads to a production increase. A candidate for the technology was identified in a 36”, 47km long production trunk line offshore Egypt. A preliminary flow assurance study was performed to assess the feasibility of the
foamer technology application by means of simulations of the production system at different operating conditions and
with different liquid loading levels. The analyses suggested a potential pressure drop decrease and consequent production increase of a few per cent. Consequently, a field test was performed.
The results of the field application demonstrated that it was possible to increase gas production in the range 5-15%
and remove the liquid accumulation without affecting the normal production operations. The paper shows the stages
of the working process and demonstrates the capabilities of the foamer technology for pipeline deliquification.
Notes:
2015 Gas Well Deliquification Workshop
Page 20
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: V --- Chemicals --- SelecSession Chair:
tion, Installation, Optimization
Fenfen Huang
Jason Carmichael
Presentation Title: V – 2
Company(ies):
New Insights in Desktop Scale
TNO
Foamers Selection Methods for Gas
Well Deliquification
Author(s):
Contact Information:
Pejman Shoeibi Omrani
erik.nennie@tno.nl
Erik Nennie
Daniel Turkenburg
Frank Vercauteren
Abstract:
Foamers are extensively applied worldwide to deliquify gas wells. In order to be effective, the surfactant chemicals
should form a stable foamer when combined with field brine and condensate under field conditions. To ensure good
foamer performance in the field, lab testing is conducted beforehand to test foamer performance. A wide variety of
test methods are currently being used to perform these tests. On the other hand, most of the current test methods
and apparatus are capable of evaluating foamers at conditions which are not representative for field conditions. This
can lead to a mismatch between the lab tests and field experiences as a result of incorrect foamer selection. Hence,
there is a clear demand for a standardized test method to evaluate foamers performance at more representative
conditions to field.
A new desktop scale setup was designed to incorporate the currently available foam testing methods into a single
setup. The newly designed setup has an extended operational ranges compared to current setups. Foamers performance could be evaluated at elevated pressure and temperature and in the presence of field brine and condensates.
In the measurements 6 parameters are varied with the following ranges:

Pressure: 1 to 15 bara

Temperature: 25 to 150 °C

Water salinity: 0 to 20%

Hydrocarbon fraction : 0 to 70%

Foamer concentration: 100 to 1000 ppm

Foamer agitation velocity (gas superficial velocity): 0.01 to 0.2 m/s
The results of measurements give new insights to the effect of each parameter and the combination of parameters on
the foam behavior. The initial measurements show that gas velocity, foamer concentration, and hydrocarbon fraction
have significant effect on the foamer performance. The effect of pressure within the measured ranges on foam behavior is marginal and the temperature and salinity effects seem to be dependent on the type of tested surfactant.
Notes:
2015 Gas Well Deliquification Workshop
Page 21
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: V --- Chemicals --- SelecSession Chair:
tion, Installation, Optimization
Fenfen Huang
Jason Carmichael
Presentation Title: V – 3
Company(ies):
Pressure Drop Prediction under
The University of Tulsa
Foam Flow Conditions
Author(s):
Contact Information:
Ayantayo Ajani
mohan@utulsa.edu
Mohan Kelkar
Cem Sarica
Eduardo Pereyra
Abstract:
Foam lift is one of the most cost effective methodologies for unloading gas wells. The surfactants are either injected
intermittently or continuously to lift the liquid to the surface. By reducing the gravitational gradient and increasing the
frictional gradient, the minimum point on the tubing curve is shifted to the left, thus unloading the well. Although
foam lift is a popular technique, currently, we do not have a methodology to predict the pressure drop under foam
flow conditions. When foam lift is installed, the operator is interested in correctly predicting the pressure drop for
foam flow as a function of the type of surfactant as well as the surfactant concentration.
To address the calculation of pressure drop under foam flow conditions, we measured several foam flow characteristics in both small scale and large scale facilities. Small scale facilities involved measurement of foam break as a
function of time as well as foam carryover capacity as a function of surfactant concentration. Large scale facility involved measurement of pressure drop in 2” and 4” tubing which is 40 feet tall. The reason for collecting the data in
small scale facility is to be able to use that data to predict the pressure drop in large scale facility. Specifically, we
developed liquid hold up correlations for five different surfactants using only the small scale data. Small scale data
are much easier to obtain and replicate. We observed mostly annular flow in pipe with liquid film replaced by foam
film. Using the annular flow model, we developed a new correlation to calculate the pressure drop under foam flow
conditions. We compared our model results with actual measurements in the large scale facility. Our model is reasonably able to predict the pressure drop within ± 30 %. The reason for such large variance is that the small scale
facility is not able to see all the characteristics of the foam which are observed in large scale facility. For example,
liquid unloading capability does not change significantly beyond certain concentration (we use this parameter to calculate liquid holdup); however, increase in surfactant concentration always result in increase in pressure drop. This
disconnect results in relatively larger variance in predicting the pressure drop under foam flow conditions.
The developed correlation is the only correlation which is currently available to calculate the pressure drop under the
foam flow conditions. It is superior to conventional annular flow equations. Further, the correlation does not need
collection of data in large scale facilities. We have done some preliminary testing of this correlation with limited field
data and the results look reasonable.
Notes:
2015 Gas Well Deliquification Workshop
Page 22
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: V --- Chemicals --- SelecSession Chair:
tion, Installation, Optimization
Fenfen Huang
Jason Carmichael
Presentation Title: V – 4
Company(ies):
Foam Flow Investigation in Large
The University of Tulsa
Scale Facilities – Experimental Data
and Observations
Author(s):
Contact Information:
Ayantayo Ajani
mohan@utulsa.edu
Mohan Kelkar
Cem Sarica
Eduardo Pereyra
Abstract:
Foam lift is one of the most cost effective methodologies for unloading gas wells. The surfactants are either injected
intermittently or continuously to lift the liquid to the surface. By reducing the gravitational gradient and increasing the
frictional gradient, the minimum point on the tubing curve is shifted to the left, thus unloading the well. Although
foam lift is a popular technique, several questions related to foam flow remain unanswered: (i) what is the primary
mechanism by which the liquid loading is eliminated?; (ii) how can we predict the inception of liquid loading under
foam flow conditions?; (iii) how does the concentration of surfactant impact the liquid unloading; (iv) what type of flow
regime exists under foam flow conditions?; and (v) how is the pressure drop in tubing is impacted by the presence of
foam?
To investigate these questions, a test facility was constructed consisting of both 2” and 4” pipes which are about 40
feet tall. Gas and liquid phases were mixed and flowed through these two pipes. Five different surfactants (anionic,
cationic, amphoteric) were investigated. We measured pressure drop, and liquid holdup using quick closing valves
for different surfactant concentrations. In addition, various flow regimes were recorded using high speed video camera. We considered wide ranges of gas velocities and liquid velocities typical of gas wells.
Our experimental data resulted in the following observations:
1. The presence of surfactant can significantly shift the minimum on tubing curve to the left; however, the effect
of surfactant is diminished for larger diameter pipes.
2. The surfactant concentration does have an impact on the minimum point; however, the shift is small and
relatively insensitive to the surfactant concentration beyond certain concentration.
3. The most common flow regime under foam flow is annular flow except that instead of liquid film, foam film
flows on the wall.
4. By comparing the pressure gradient due to friction and pressure gradient due to gravity as a function of gas
velocity, we can predict the inception of liquid loading under foam flow conditions
5. The pressure drop under foam flow conditions is strongly related to the surfactant concentration. Higher the
concentration, higher is the pressure drop.
6. The optimum surfactant concentration is not necessarily critical surfactant concentration. Higher concentration results is significant increase in the pressure drop and more stable foam while only slightly decreasing
the minimum velocity at which liquid loading starts. Large pressure drop means less rate and stable foam
means more difficulty in separating it at the surface conditions.
Notes:
2015 Gas Well Deliquification Workshop
Page 23
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: V --- Chemicals --- SelecSession Chair:
tion, Installation, Optimization
Fenfen Huang
Jason Carmichael
Presentation Title: V – 5
Company(ies):
Web Based 3D Wellbore
Wansco
Viewer
Author(s):
Contact Information:
Walter Phillips
walter@wansco.com
Abstract:
Common wellbore visualizations are depicted using 2D perspective views. This approach is limited and
potentially misleading. Of particular interest to rod-pumping and progressing cavity pumps is the amount
of side loading placed on the rod string throughout the wellbore. By illustrating the trajectory of a wellbore
in 2D, some nuanced geometries can be easily lost. The familiar “corkscrew” wellbore, for example, is
very difficult to depict through simple perspective views. A corkscrew is best visualized at a specific angle
where the shape is apparent. This best viewing angle is generally not at 90 degrees, where typical perspective views are generated.
Distributed wellbore visualization tools can be applied to both design and analysis of pump installations.
Interactive views help to identify points in the well where problems may occur, or have occurred. Strategic
placement of downhole equipment such as pump depth relative to perforations and historic fluid levels
can be done in a more intuitive way, taking into account a more accurate understanding of the wells geometry.
The use of standards based modern web technologies enables rapid deployment of this tool to both desktop and mobile devices. Three dimensional graphics acceleration was previously only available in the
web browser through plugins and other third party software installations. 3D graphics can now be rendered natively in most modern web browsers without the need for any additional software.
Notes:
2015 Gas Well Deliquification Workshop
Page 24
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: V --- Chemicals --- SelecSession Chair:
tion, Installation, Optimization
Fenfen Huang
Jason Carmichael
Presentation Title: V – 6
Company(ies):
Comparing Annular Flow through
Black Gold Pump and Supply Company
Tubing Anchors
Author(s):
Contact Information:
Walter Phillips
walterp@blackgoldpump.com
Abstract:
Tubing anchors introduce a restriction in the casing annulus which can negatively affect annular gas flows. Two tubing anchor types are compared in a scale model simulation.
Traditional mechanical anchors take up a great deal of annular area and may restrict, or even impede annular gas
flow under some conditions. The hydraulic tubing anchor has a different structural geometry allowing for a larger
overall bypass area. In addition, the shape of the hydraulic anchor gathers the bypass area into two large regions, as
opposed to a thin ring around the perimeter. This shape allows for increased gas flows, as well as better handling of
solids. To illustrate and test this, parallel scale models of both types of anchor were placed in a transparent casing
annulus. Various tests were conducted including gas flow and handling of solids.
Notes:
2015 Gas Well Deliquification Workshop
Page 25
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: VI --- Automation, OptimiSession Chair:
zation
John Green
Walter Phillips
Presentation Title: VI – 1
Company(ies):
Power of SQL at the Wellhead
Flow Data
Author(s):
Contact Information:
Paul Brennen
shelley.m@corporategroupinc.com
Eddie Mechelay
Abstract:
Methods of capturing data from the wellhead were designed around older technologies. The advancement of Ethernet communications has opened the door to the use of modern technologies of data storage, transfer, and management.
The back office now has a direct line to key, decision-driving data.
 High resolution data (trending and alarm history)

Database applications (liquid transfer truck ticketing)

High-end data analysis
High resolution data analysis can be done at the wellhead instead of moving data back to a main server for computation. This is a switch in the approach to wellhead data analysis and optimization. When SQL is available, this circumvents antiquated SCADA protocols used to retrieve big data from the field.
Advantages

Data is stored in a database instead of limited RAM memory

Transaction based applications are possible at the wellhead

Trending, alarms and operator actions are stored in a historian
Smarter Solution

High resolution data analysis and optimization can take place at the wellhead

High resolution and detailed logging provides operators a better tool for working the well

Database driven form applications drive efficiency and safer production
SQL Changes Data Retrieval

Data is retrieved using standard SQL query - unlike the multilayer SCADA protocols

SQL databases offer a higher level of security, encryption and data integrity
Industry Case
Nowhere is the measurable success of SQL better demonstrated than in the process of transferring liquid chemicals,
water, or raw materials to and from the wellhead. Flow Data can demonstrate the return of an Ohio producer who
found lost profit by taking control of data produced from liquid volume measurements.

Transfer volumes are accurate and verifiable through integrated digital instrumentation

Truck haulers required little or no training with panel interface, reducing mistakes in transfer protocol

Digital ticket data uploaded transfer volumes directly to accounting systems
Notes:
2015 Gas Well Deliquification Workshop
Page 26
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: VI --- Automation, OptimiSession Chair:
zation
John Green
Walter Phillips
Presentation Title: VI – 2
Company(ies):
Drive Down Your Costs With WireOleum Tech
less Automation
Author(s):
Contact Information:
Jim Gardner
ekorotich@oleumtech.com
Abstract:
In today’s volatile market prices can fluctuate quickly. There is little we can do to effect the price of a barrel of oil
however there are many things we can do to minimize lifting costs and maximize profitability. Many operators have
taken a holistic approach towards maximizing the production and minimizing the cost at the same time. Extracting
maximum possible resources from the wells (tantamount to increased well-life) is of primary concern but that should
be complemented with improved surface logistics. The methods of optimization have undergone a radical change in
past few decades. Many lifting systems also have a real-time well monitoring system in place collecting vital data to
facilitate decisions. With the rise in adoption of advanced technology, operators have developed innovative ways to
curb issues that caused costly downtime and losses previously. With new automated production instrumentation,
operators are finding a level of production optimization and safety never thought possible before. Many analysts say
that implementation of Digital automation increases the value of a field by 25% by optimizing production and increasing the life of the field.
Along with the addition of new instrumentation focused on the Oil and Gas Industry one of the biggest trends in the
past 10 years has been the migration from wired technology to wireless technology. Today with the era of multi-well
pads and central tank batteries a single location may have 50 or 60 instruments measuring the processes on a location. Wireless can cut the installation of that equipment from a 2 or 3 man crew working for weeks to a one man crew
working hours.
Notes:
2015 Gas Well Deliquification Workshop
Page 27
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: VI --- Automation, OptimiSession Chair:
zation
John Green
Walter Phillips
Presentation Title: VI – 3
Company(ies):
Wireless I/O, Connecting Remote
Freewave Technologies
Sensors in a Wide Range of Environments
Author(s):
Contact Information:
Glenn Longley
ctrowbridge@catapultpr-ir.com
Abstract:
Production demands of the 21st-Century are increasing at an extraordinary pace. Several industrial markets face
challenges going forward, including reliable real-time monitoring of assets, dealing with 24-hour production demands,
and managing high costs in terms of both time and resources to manage assets in remote locations.
Monitoring remote sensors presents a unique set of challenges to remain cost effective, safe and secure with installations in all different types of environments and distances. Wireless IO can bring back data from sensors that are anywhere from a few feet to 30+ miles away. These systems can connect to a PLC/RTU or go all the way back to a
central SCADA system.
This presentation will review several example installations and provide an overview of the challenges that Wireless
IO can help solve, whether installing in regular or hazardous location. This presentation also includes considerations
necessary for Class 1 Division 2 and Class 1 Division 1 explosive gas locations that are common in Oil and Gas industry.
Notes:
2015 Gas Well Deliquification Workshop
Page 28
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: VI --- Automation, OptimiSession Chair:
zation
John Green
Walter Phillips
Presentation Title: VI – 4
Company(ies):
Multi-Well Automated Chemical Op- PCS Ferguson
timization Solution
Author(s):
Contact Information:
Mike Rost
mike.rost@doverals.com
Abstract:
Problem:
Historically, gas wells have received chemical treatments using batch or a single pump and single controller per well.
This one to one ratio proved to be expensive, maintenance intensive and required a large footprint on the location.
With chemical treatment being the second largest expense for an operator on a producing well, their attention has
become focused on efficiency improvements in this area.
Challenge:
When it comes to choosing an optimized chemical injection solution operators are starting to realize they must control/manage the expense through more reliable, accurate and intelligent systems. The pain for operators is not knowing how much chemical is being injected or if it is being injected and this ultimately affects gas production.
Solution:
Injecting based on volume rather than time, eliminating one of the largest sources of chemical waste in the industry.
As chemical leaves the tank, it is injected through a single pump. Before traveling to a particular well, through a solenoid valve, a positive displacement flow meter reads and accumulates volume and is accurate down to .1% of span.
To ensure chemical is only being introduced into the desired well, a flow switch is located downstream of the injection
point to return a signal of positive flow when the pump is on. Once the desired volume has been accumulated for a
particular well by the flow meter, that well’s valve is closed and the sequence repeats for the next X wells, injecting its
required volume. These volumes, as well as all other process variables, are available to the operator remotely via
any web browser. This ultimately gives an operator unlimited remote visibility into his chemical injection program.
Results:
The presentation will provide an overview of the solution and review case studies from several sites and provide:

Accuracy of chemical delivery – Over pumping chemicals is among the largest sources of waste in the industry.

Accurate injection means better production – By accurately administering the chemical injection program,
operators are seeing reduced negative effects in wells and reduced expenses related to work overs and
maintenance.

Reduced man hours - Remote visibility into their chemical program, allows operators to sort by exception,
reduce man hours for operational procedures such as rate changes, pump priming and daily inspection.
Operators are seeing reduced expenses in their HSE organization as well.
Notes:
2015 Gas Well Deliquification Workshop
Page 29
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: VI --- Automation, OptimiSession Chair:
zation
John Green
Walter Phillips
Presentation Title: VI – 5
Company(ies):
Peeling the Onion: Why Automation BP
Data is More Valuable Than You May Blackstone Instruments
Think
Author(s):
Contact Information:
Justin Diven
justice.diven@bp.com
Randy Koenig
John Bowman
Abstract:
Blackstone Instruments has been working with BP to develop a detailed model of the behavior of gas wells. This project has relied heavily on interpreting raw automation data from Wyoming which presented numerous challenges to
numerical analysis. The ongoing interaction between the model and the automation data has permitted teasing out
new information about the flow mechanisms at play which were not possible to extract from simple rate and pressure
trend observations.
This presentation will discuss the challenges and approaches used to clean up the raw data and some of the ways
we’re using it.
Presentation Overview:
●
●
●
●
●
●
●
●
●
Overview of common well configuration and automation data collection process
Overview of OSIsoft PI data formats
Issues – Data tags use different time stamps (Use PI time step function)
Issues – Data tags had missing or error values (filter)
Issues – Data tags had anomalous values (surface choke, downhole redistribution of fluid – go to the site,
look into specific cases)
Ways we’re using the data: Liquid loading can be estimated as a function of time from automation data
(graph(s)).
Ways we’re using the data: Liquid re-orientation explains the sudden jump in tubing pressure in the first few
minutes of shut-in: gas initially trapped below the liquid works its way to the top (graph).
Ways we’re using the data: Potential insights about near wellbore IPR and fracture storage volume.
Conclusion: there is not a bump or squiggle in automation data that does not mean something. How much
we learn from this is up to us!
Notes:
2015 Gas Well Deliquification Workshop
Page 30
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: VII --- Pumps, ESP, PCP,
Session Chair:
Hydraulic, Misc.
Norm Hein
Jim McCoy
Presentation Title: VII – 1
Company(ies):
Results of Hydraulic Piston Pump
NAM
Field Trial
Cormorant Engineering
BakerHughes
Author(s):
Contact Information:
Kees Veeken
Kees.Veeken@shell.com
Sjoerd den Daas
Tim Ebare
Erik Riemsma
Bert Lugtmeier
David Bolt
Travis Bolt
Armand Vasseur
Abstract:
The number of liquid loading gas wells in NAM will steadily increase over the coming years and different techniques
are currently being field tested to delineate their role in the future deliquification strategy.
This paper presents the results of a field trial with a low-rate hydraulic piston pump. First, it describes the downhole
and surface equipment and the mode of operation. Second, it presents the deployment of the pump utilizing concentric coiled tubing. Third, it reports the results of the field trial including detailed surface and downhole surveillance
data.
The field trial confirmed the technical viability of the pump. The next step is to permanently install this pump to
demonstrate sufficient reliability before applying it in other wells.
Notes:
2015 Gas Well Deliquification Workshop
Page 31
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: VII --- Pumps, ESP, PCP,
Session Chair:
Hydraulic, Misc.
Norm Hein
Jim McCoy
Presentation Title: VII – 2
Company(ies):
Gas Assisted Rod Pump
GARP Services LLC
A subsidiary of Evolution Petroleum Corp
Author(s):
Contact Information:
Daryl Mazzanti
dmazzanti@evolutionpetroleum.com
Abstract:
GARP® is an artificial lift system that combines a down-hole pump with gas lift in a two stage lift process that lifts
liquids to the pump instead of lowering the pump to the liquids. The technology has applications in casing sizes of 41/2” or larger for wells with:
1) horizontal or deviated sections
2)
high gas to liquid ratios or gas slugging problems
3)
long perforated intervals
4)
reservoirs that are too deep for conventional lift systems
Conventional artificial lift methods are not efficient in these regions or conditions due to higher operating expenses
and gas and solids interference in the pump. Since GARP® lowers the bottom hole flowing pressure by lowering the
artificial lift depth, it not only increases production but also add reserves over conventional artificial lift methods. The
down-hole pump is kept above the problem areas described above, while relatively low pressure, low volume gas is
used to lift liquids in these regions a short distance up to the pump (not the surface as in conventional gas lift).
GARP® incorporates a very efficient gas separation design that allows for flow rates of up to 1200 BFPD without gas
interference in the down-hole pump.
To date, GARP® has been installed on horizontal wells in the Giddings Field in central Texas, resulting in economically sustained production increases over previously installed conventional artificial lift systems. GARP Services, LLC
is seeking industry support in expanding this technology to other areas, which would include the installation into applicable vertical wells.
Notes:
2015 Gas Well Deliquification Workshop
Page 32
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: VII --- Pumps, ESP, PCP,
Session Chair:
Hydraulic, Misc.
Norm Hein
Jim McCoy
Presentation Title: VII – 3
Company(ies):
Development of the “RapidJet”
Source Rock Energy
Method of Gas Well Deliquification
C-FER Technologies
Enerplus Corporation
Author(s):
Contact Information:
Kelly Falk
Kelly.Falk@sourcerock.ca
Daniel Booy
Bill Clay
Abstract:
Due to low gas prices, operators have had a difficult time economically removing unwanted liquids from shallow gas
wells. In response to this, a group of operators came together to investigate new, novel and inexpensive artificial lift
technologies to remove these liquids.
After a custom “flow loop” was designed and constructed at C-FER Technologies to replicate shallow gas well conditions, a number of artificial lift systems, including the Source Rock jet pump, were successfully tested. Although it
was determined that dewatering a low rate shallow gas well using a continuously operating jet pump was likely not
the most economical solution, jet pumps could be used by installing the downhole equipment into a large number of
wells, then utilizing a mobile power fluid pump at surface to dewater one well at a time.
To test this “Rapid Jet” concept, a Source Rock jet pump was installed in a controlled test well and operated with
various nozzle and throat combinations, while various key operation variables were measured. It was found that the
connection of a pressure truck to the wellhead was simple, switching from one nozzle and throat combination to another was quick and easy, and the pump was able to pump down a 200 ft fluid column down to the pump intake within 15 minutes (a maximum production rate of approximately 350 bpd was achieved). Based on these tests, it would
be reasonable to assume that this method could be successfully used to dewater several wells each day with minimal
labor costs and no service rig or CTU costs.
Since the results of this study have shown that the process is technically feasible, one operator is currently planning
a two-well field pilot. However, further design and testing work, preferably on a larger scale, would help to further
optimize the process.
Notes:
2015 Gas Well Deliquification Workshop
Page 33
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: VII --- Pumps, ESP, PCP,
Session Chair:
Hydraulic, Misc.
Norm Hein
Jim McCoy
Presentation Title: VII – 4
Company(ies):
Capillary Injection for Rod Pump
Weatherford
Applications
Author(s):
Contact Information:
Randy Matthews
Randy.Matthews@weatherford.com
Abstract:
There are many oil and gas fields across the United States which have been producing for over 100 years or more.
The barriers that exist to prevent such extended field life are many. Those issues include rod and rod pump failures,
damage to the tubing, paraffin/ scale deposition, salting and corrosion. All of these can present challenges of how to
deal with the problem and correct it, while maintaining economic visibility of a field.
Tackling these issues has mostly been done using batch treatments with various preventative chemicals which over
the years have proved to be expensive and not very effective as it cannot pinpoint the problem directly. More
recently the use of capillary injection strings, attached to the outside of the production tubing, has provided a means
of injecting more precise volumes of chemicals. These strings have also been used to deliver fresh water closer to
the source of the problem. However, on rod pump wells the point of injection can only be made above the tubing
anchor; thus failing to protect the down hole pump and internals of the production tubing string. A new design of tubing anchor is now available which incorporates a pass-through capability for a capillary injection string thus enabling
pinpoint injection for chemical and fresh water treatment capabilities for the pump, as well as protection for your rods
and tubing for longer run times.
In this presentation, the author will review the history of chemical treatment methods and describe the use of a new
tubing anchor design that addresses the shortcomings of current chemical injection techniques as well as case histories for different well issues, treatment methods, cost savings and increasing run times.
Notes:
2015 Gas Well Deliquification Workshop
Page 34
2015 Gas Well Deliquification Workshop
Technical Presentations
Session: VII --- Pumps, ESP, PCP,
Session Chair:
Hydraulic, Misc.
Norm Hein
Jim McCoy
Presentation Title: VII – 5
Company(ies):
Hydraulic PU’s Continue to Prove
Memorial Resource Development
Effective in Gas Well Deliquification
Author(s):
Contact Information:
Jess Babbitt
jess.babbitt@memorialrd.com
Abstract:
An SPE paper was presented in October, 2010 in San Antonio titled “Hydraulic PU’s Proving Very Successful in Deliquifying Gas Wells in East Texas”. This paper will be briefly summarized and updated to show continued positive
deliquification results and low failure frequencies. New East Texas installations continue to perform well. One HPU
was installed in an East Texas horizontal well with the pump in the horizontal portion of the wellbore and it has performed well. Several HPU’s have recently been installed in South Texas and are having great results. One was installed in South East Texas at a depth of 14,000’ and hopefully there will be a story to tell on that well. The presentation will present several case histories of HPU installations. Recent experiences with other companies and high failure frequency of conventional PU’s compared to HPU’s will be discussed.
Notes: