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Production Engineering Experience with the First Intelligent Field Implementation at Haradh-III
valve settings as opposed to on/off valves.
3
As can be seen from
Figure 1: Aerial Map of Haradh-III Showing Well Distribution
3
Figure 1, the complex array of 132 laterals in over 30 wells, coupled
with challenging reservoir characteristics, requires close monitoring
and proactive measures to prevent any adverse production
performance conditions. Therefore, the field was developed as an
North
I-Field, equipping the wells with all necessary accessories and
implementing a supervisory control and data acquisition (SCADA)
system that ensures all data are monitored in realtime and enables
OWC
remote control of the wells.
As can be seen from Figure 1, typical Haradh-III wells are drilled as
multilateral wells (predominantly trilateral wells) and equipped with
smart completion. Smart completion assemblies are installed across
Producers
Power water injectors
each lateral to choke or completely isolate the production from Observation wells
GOSP-3
specific laterals. Control lines are extended from each smart
completion assembly downhole to a surface control panel in order to
GOSP = gas–oil separation plant.
operate the valves.
4
In addition, a PDHMS is installed above the
Figure 2: General Schematic of the Haradh-III Smart Wells
upper packer, providing continuous bottomhole pressure and
Showing the Data Transmission Path
temperature measurements.
End-user
At the surface, transmitters are installed to provide wellhead
pressure, temperature and annuli pressure. Such data are critical to PI server
ensure tubing and casing integrity. The surface choke valves are of
the electronic type that enable local control as well as remote control
GOSP-III
Q Q Q
from the gas–oil separation plant (GOSP). At each well, an MPFM
P T
T %
MPFM
RTU
unit is installed, providing continuous flow measurements of the
Choke
Fibre optic
valve
three different phases: oil, water and gas. This was an essential
P P
P
requirement as testing these multilateral wells is more complicated,
requiring stable flow at various surface levels as well as downhole
T P
choke settings for each lateral.
All of the data acquired are transmitted via fibre optic cables to a
remote terminal unit (RTU) at each well site, and then connected via
GOSP = gas–oil separation plant; MPFM = multiphase flow meter; RTU = remote terminal unit.
the fibre optic network to the SCADA system at the GOSP. The data
can be viewed by intended end-users at their workstation through
Figure 3: Snapshot of One of the Systems Used to Monitor
designated corporate servers. The data can be retrieved via
Realtime Data
spreadsheets or specialised easy-to-use software (see Figure 2). The
aim of such a mega-scale project is to enable remote and continuous
monitoring of complex wells in this critical area of the field and
accelerate not only the decision-making but also the decision-
implementation process.
Field Case Histories
I-Fields theoretically propose genuine solutions; however, there
remains much uncertainty as to how they can be applied to maximise
recovery and enhance field operations.
5
The experiences of Saudi
Aramco, one of the largest operators in the industry, with
implementation of I-Fields has been quite successful and is believed to
have provided substantial momentum to the industry in the area of
I-Fields. In the remaining portion of this article, various real examples
of production engineering experience with I-Fields will be cited. The subject well, Haradh-A, is a trilateral smart well, as depicted in Figure
3. The well is located in the central sector of the field and was making
Production Optimisation of a Multilateral Well 8,500B/D dry production at a flowing bottomhole pressure (FBHP) of
As all Haradh-III wells are drilled as multilaterals and completed as 1,930psi, which is a relatively low FBHP compared with offset wells. Prior
smart wells, continuous optimisation was essential to ensure optimal to the test, the static bottomhole pressure (SBHP) was taken on each
field performance. Therefore, production testing jobs were lateral. After that, the well was put on production. Each lateral was flowed
conducted on over 30 multilateral wells with the purpose of individually at different downhole choke settings. Table 1 shows the
equalising downhole withdrawal. comparison between the downhole choke settings before and after
EXPLORATION & PRODUCTION – VOLUME 7 ISSUE 1
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