08-03-15 muth pump
Post on 21-Jan-2018
155 Views
Preview:
TRANSCRIPT
Muth Pump LLC
•
Extending Downhole Rod Pump Run Life 300% Using
New Technology.
07-13-15Muth Pump LLC 1
Mark Meza
&
Garold Muth
Conventional Plunger From a Well With
Sand Present
07-13-15Muth Pump LLC 2
Conventional APIPlunger
07-13-15Muth Pump LLC 3
07-13-15Muth Pump LLC 4
60 Thousandths
Connector
Plunger Walls
2 Thousandths
Pull Rod
07-13-15Muth Pump LLC 5
07-13-15Muth Pump LLC 6
07-13-15Muth Pump LLC 7
Funnel
The Funnel Effect
Sand and/or Solids are being
forced down and outward into
the gap due to the shape of the
standard API connector.
07-13-15Muth Pump LLC 8
07-13-15Muth Pump LLC 9
07-13-15Muth Pump LLC 10
Wedge
When Sand or Solids are present
and you are using a POC’s with a
conventional plunger you will likely
get stuck due to the wedge effect.
The Wedge Effect
07-13-15Muth Pump LLC 11
Conventional “FARR”
From
To
07-13-15Muth Pump LLC 12
Conventional “FARR”
.060.002
97 %Reduction
07-13-15Muth Pump LLC 13
Conventional “FARR”
.060.002
97 %Reduction
07-13-15Muth Pump LLC 14
Conventional “FARR”
.060.002
Funnel
07-13-15Muth Pump LLC 15
Conventional “FARR”
.060.002
Wedge
07-13-15 Muth Pump LLC 16
07-13-15Muth Pump LLC 17
07-13-15Muth Pump LLC 18
Extending Downhole Pump Run Life using Ingenuity Innovation and New Technology Lead to
Reduced OPEX and Increased Revenue in the Duri Steam Flood (DSF), Indonesia.
SPE-145249-PP
In DSF, > 700 Pump Stuck (PS) jobs are performed each year which primarily caused by sand production. Annual total cost of this routine
service work is multimillion dollar. In addition, with average of 3 days downtime/PS job, there is over 2,100 days of lost production associated
with downtime. With currently over 5,000 active producer wells, identifying artificial lift SRP alternatives that can improve run life and reduce
number of PS jobs performed would result in lower OPEX (*Operating Expense) (less PS jobs), higher production (reduced downtime), and
lower risk of HES (*Health, Environment, Safety) incidents (less rig work).
Three viable options were identified for a field trial after soliciting ideas and opinions from Service Suppliers, MSS (*Maintenance Supports &
Services) Team, and Chevron Global Network to overcome these pump stuck issue:
0.015" fit Tubing Pump
Stroke-Thru Pump
0.002" fit FARR Plunger
The 2008-2009 PMT (*Production Management Team) HOOU (*Heavy Oil Operation Unit) Artificial Lift Lean Sigma confirmed that these
artificial lift options had a longer run life than the standard 0.010" fit pump. Average run life was increased by 93 days, and 70% of the time
produced a longer run life. During 12 months trial period, there was an average reduction of 12 PS jobs/month compared to baseline data.
Since the 0.002" fit FARR Plunger had encouraging results in low wellhead temperature wells, there was initiative to evaluate it in higher
temperature by modifying the pump fit to 0.005" considering thermal expansion. In 2010, 15 units of 0.005" fit FARR plungers were tested,
replacing either a Stroke-Thru or 0.015" Fit Pump that had failed. The results were encouraging and indicated that the 0.005" FARR Plunger
exceeded the run life of the previous pump 71% of the time with additional incremental run life of 44 days.
Author
Aan Akhmad Prayoga
Petroleum Engineer
PT Chevron Pacific Indonesia
Abstract Submitted for APOGCE 2011
07-13-15 Muth Pump LLC 19
In January 2013 a prominent
Kern County Oil Company (Aera)
completed a Six Sigma Study of the
FARR Plunger. The study found that
the FARR Plunger increased run
times 300% in their oil wells
equipped with FARR Plungers.
All of these wells had high
concentrations of sand and failure
rates due to sand. This study
compared the FARR Plunger to other
“Sand Pump Plungers” (Sand Pro),
(3-Tube), (-10 Conventional), (Sand
Flush) and etc.
07-13-15 Muth Pump LLC 20
Six Sigma Study
Plunger Count Failed % Still Running
Farr 188 94 50.00%
Non Farr* 205 182 11.22%
Significance:
• 50% of all Farr plungers are still running.
• Only 11.22% of all Non-Farr* plungers are still running.
• The large percent of Farr plungers still running requires that
we rely on the projected median runtime in the survival plot
analysis to explain the data.
2015 Coalinga Study Data Overview
*The study only looks at wells that have had a Farr plunger in them. Only two Non-Farr pump pulls prior to the Farr being installed and any Non-
Farr pump pulls after the Farr was pulled were included in the study. The Non-Farr category includes a variety of plunger types. This applies to all
slides pertaining to the 2015 Coalinga Study.
07-13-1521Muth Pump LLC
Muth Pump LLC
Non-FarrFarrCombined
Non-FarrFarrCombined
--- Non-Farr--- Farr
The projected median runtime
for Farr is 470 days.
The projected median runtime
for Non-Farr is 217 days.
The Farr has a 216% longer
projected median runtime
than the Non-Farr.
This is a 116% improvement.
2015 Coalinga Study
Survival Plot
7-13-15 22
Scenario:
If 100 Non-Farr plungers are replaced with Farr
plungers in one year, then there would be a total
yearly savings of $874,368.
2015 Coalinga StudyEconomic Analysis
Savings/well/year
$8,744
Cost/pull Projected median runtime Cost/well/day Cost/well/year
Farr $10,400 470 days $22 $8,077
Non-Farr $10,000 217 days $46 $16,820
237-13-15
Muth Pump LLC
07-13-15 Muth Pump LLC 24
Increase Pump Life 3-6 Times Longer
Studies in California, Indonesia, and Venezuela have all
shown the FARR Plunger out-performs other rod pump
plungers. Increasing run life an average of 3-6 times.
07-13-15 Muth Pump LLC 25
Reduce Environmental Spill Incidents
There is an increased risk for a spill or an accident every time you have to pull a
pump from a well. Sometimes when a pump is stuck you have to pull the whole
tubing string to retrieve the pump and get the well operational again. This could
result in costly spills or other problems. Spills could prompt a visit from the
EPA.
07-13-15 Muth Pump LLC 26
Reduce Health & Safety Incidents
Most oilfield accidents occur when you have rigs or other work over equipment
on site. You have more personnel in the area and a greater risk for injury.
Because the FARR Plunger will keep your pumps in the ground longer there will
be fewer well pulling’s which reduces the risk for injury.
07-13-15 Muth Pump LLC 27
BY MAKING ONE SMALL CHANGE TO YOUR STANDARD
API DOWN HOLE ROD PUMPS, YOU WILL:
MAXIMIZE PRODUCTION AND EFFICIENCY
MINIMIZE HEALTH, SAFETY,
& ENVIRONMENTAL RISKS
INCREASE PUMP RUN LIFE
Reduce well pulling
Reduce pump repairs
Save thousands of $dollars$ in the long run
07-13-15 Muth Pump LLC 28
top related