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Wellhead & Wellstream
Desanding Solutions for
Offshore Production in Malaysia
Produced Water Society – 24th Annual Conference
January 14-16, 2014
Houston, Texas, USA
Presented by: Steve Coffee
Overview
• Solid Problems
• Solution
• How It Works
• Testing, Pilots & New Installations
• Results
• Other Technologies Considered
• Conclusions
Solids Problem
The degree of sand production is dependent upon several factors,
the most common are listed below:
- degree of consolidation
- completion
- sand grain size
- uniformity of the sand
- anisotropy
- overburden and reservoir pressure regime
- permeability
- fluid production rate
- permeability
- oil viscosity
Sand Production
0 100 200 300 400 500 600 700 800
20
15
10
5
Cumulative Sand Production by Volume, m3
Production Rates Vs. Cumulative Sand ProductionAfter Loughead & Saltukaroglu, 1992
Oil
& F
luid
Pro
duct
ion R
ate
s, m
3/d
ay
Fluid Rate Oil Rate
Figure 2
Solution
ESI Desander
How It Works
Enerscope Desander Performance
Particle Sizes in the
System
Solids Distribution in
the System
Enerscope
Capability
Expected
Enerscope
Performance
> 74 Microns 15% 98% 14.7%
74 – 40 Microns 30% 95% 28.5%
40 – 20 Microns 35% 84% 29.4%
< 20 Microns 20% 50% 10.0%
Aggregate Solids Removal Capability: 82.6%
Initial Testing
TE-45 : - Production = 900 bpd (water cut 0%)
- GOR = 0.5 Mscf/stb.
- Sand production 20 pptb (lb/1000 bbl)
- Sand size ranges from 20 to 125 mesh
- Production expected to start at 400 bpd
BO-210L: -Production = 800 bpd (water cut 50%)
- GOR = 0.8 Mscf/stb.
- Sand production 20 pptb (lb/1000 bbl)
- Sand size > 100 mesh
- Production expected to start at 400 bpd
Desander Offshore
Initial Testing
BOKOR B-210L
TEMANA TE-45
Production (bpd) 604 - 1050 378 - 680
Gas production (scf/stb) 500 500
Water production % 30 0
Sand particle size (micron) 50 50
Shut-in pressure (psig) 1100 470
DPEH pressure setting 16 psig 16 psig
PEH pressure setting 1050 psig 425 psi
Sand count (history) 50 PPTB N/A
Testing
New Wellhead Installations
The wells selected had the following selection criteria:
150-3,700 bbld
675-2,025 psi (46-140 barg) inlet pressure
30 to 93 C
20 to 80 mg/l of solids (slugs up to 20,000 mg/l)
5-30% water production
Solids sand, silt, grit, scale, clays, iron oxide
Oil to be light to medium
Desanding P&ID
New Desander Installations
PMO: ANGSI A, ANGSI C
SKO: BOKOR A, BOKOR C, BARONIA B, BARONIA I,
BARAM H, TUKAU A, TUKAU H, WEST LUTONG A
SBO: ERB WEST, SEMARANG B, SEMARANG F
Desanding PFD
Results
Desanding Hydrocyclones
• Multiphase capabilities
• Fine separations - effluents down to a d98 of 10 μm
• Tough ceramic inserts and materials to guard against erosion and corrosion
Other Technologies Considered
Close Pack Hydrocyclones
HC - Wellhead
EHC vs ESI
ESI EHC
Recommended Min Inlet
Pressure (psi) 35 80
Pressure Drop (psi)
3-12 30-80
D95 (μm) 40 5
Service Liquid Liquid-Gas-Multiphase
Capital Investment
1x 3x-5x
Desanders
There are a number of advantages of this
system over the desanding
hydrocyclones:
simplicity
less maintenance
less monitoring
lower CAPEX and OPEX
removal of sand upstream of facilities,
treating train and distribution
Advantages
minimal change to existing process & easy to retrofit
very low, steady pressure drop (3-12 psig/0.2=0.8 barg)
continuous solids separation with no impact of product (flow or
pressure)
efficient & environmentally friendly removal and disposal of
collected solids
small foot & lightweight
no moving parts to wear out or replace
no screens, cartridges or filter elements to be cleaned or replaced
no backwashing required
online maintenance (no downtime required nor redundancy)
minimal or no liquid loss
effective solids concentration for easy disposal/recovery
Conclusion
The desanding equipment, tried and proven in produced water
applications, is easily adaptable to wellhead conditions. This is
an excellent example of the transfer of technology further
upstream to solve more problems.
Installation of desanding equipment at the wellhead is
economical, even at sand production levels as low as 10 ppm.
There are substantial economic benefits not only to light and
medium oil areas but to any areas producing unconventional
oil.
The simplicity and the efficiency of this technology gives it an
advantage for producers the ability to bring back on marginal
wells with low production rates and that are sand producers.
Some of Our Customers
