American Oil and Gas Reporter - June 2017 - 86

SpecialReport: Artificial Lift Technology
Adjustable inputs allow the RPOT

FIGURE 1

user to specify calculation assumptions,

Recommended Optimization Actions
(Summarized View)

constraints, operating preferences, and

target operating conditions. Changes to

Convert to RF or ESP, 2 (2%)

Speed up or increase pump size, 11 (10%)

the user inputs automatically update

Slow down or decrease pump size, 7 (6%)

calculations, aggregrations and vis -

ualizations. This provides flexiblity when
operating preferences vary between users.

For example, if the maximum allowable

polish rod velocity (PRV) input was changed

from 40 to 35, more wells would generate
a slowdown or pump downsize ROA

(assuming other conditions for slowdown

or pump downsize logic are met). The

resulting ROAs are summarized in a pie

No immediate action, 88 (81%)

chart visualization (Figure 1). Selecting

pumped artificial lift systems with SCA-

incomplete pump fillage.

be made to accommodate wells that do

utilized to adjust a rod pump's target

DA, although simple modifications can
not have SCADA.

System Functionality

The ROAs generated in the RPOT

specify whether a well's artificial lift

system should be adjusted to move more
or less fluid based on the well's inflow,

Pumping speed is the first variable

production, since it does not require a

one or more components from the pie
chart brings up a list of corresponding
wells and detailed ROAs.

Another set of adjustable user inputs

workover rig or a crane (as would changing

allows ROA costs to be brought into the

other words, the most cost-effective and

ranking and budgeting of work/projects.

pump size or surface stroke length). In

time-effective actions are recommended
first.

For wells with variable speed drives,

tool. This is beneficial for continous

A summary table provides a high-level
view of the total number of ROAs, the

spending required to execute the work,

while accounting for the system's equip-

pump speed adjustments can be made

wells are part of a mature waterflood

wells without VSDs, pump speed

asset teams with the most up-to-date rod

smaller/larger unit sheave and/or motor

methodology to analyze those data. As a

ment constraints. Because the subject

and have relatively low gas/oil ratios,
the productivity index method is used to
model inflow.

The operational strategy for the rod-

pumped wells is to maximize run times

and minimize pump-offs while optimizing

drawdown. The target bottom-hole flowing
pressure is 500 psi, which corresponds

to a pump intake pressure of 200 psi.

through the drive's user interface. For

adjustments are made by changing to a
sheave. The RPOT's logic considers

changes to the motor sheave size prior to
the unit sheave since a motor sheave

change is more cost- and time-effective.

and any corresponding oil uplift.

The objective of the RPOT is to equip

pump data and to provide a consistent
result, teams are spending less time
compiling data and more time on analysis,

investigation, collaboration, planning and
budgeting.

FIGURE 2
RPOT Data Flow Diagram

Pumps are set at, or slightly above, the

typical kickoff point depth of 8,500 feet.

Pump intake pressure is targeted at 200
psi to produce at near-maximum oil

production while keeping enough fluid

above the pump to mitigate the risk of
86 THE AMERICAN OIL & GAS REPORTER

Well Info

SCADA Data

Prod Data

Equip Data

User Inputs
Master Table

Calculations

ROA Outputs
American Oil and Gas Reporter - June 2017

Table of Contents for the Digital Edition of American Oil and Gas Reporter - June 2017
