Wellhead & Wellstream Desanding Solutions for Offshore Production in Malaysia

Transcription

1 Wellhead & Wellstream Desanding Solutions for Offshore Production in Malaysia Presented by: Steve Coffee, Enerscope Systems Inc. & Ir. Azmi B. Otham, Petronas Produced Water Best Practices Conference Kuala Lumpur, Malaysia November, 2013 Overview Solid Problems Solution How It Works Testing, Pilots & New Installations Results Other Technologies Considered Conclusions 1

2 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 Production Rates Vs. Cum ulative Sand Production After Loughead & Saltukaroglu, 1992 Oil & Fluid Production Rates, m 3 /day Fluid Rate Oil Rate Cumulative Sand Production by Volume, m 3 Figure 2 2

3 Solution ESI Desander 3

4 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% Microns 30% 95% 28.5% Microns 35% 84% 29.4% < 20 Microns 20% 50% 10.0% Aggregate Solids Removal Capability: 82.6% 4

5 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 5

6 Initial Testing BOKOR B-210L TEMANA TE-45 Production (bpd) Gas production (scf/stb) Water production % 30 0 Sand particle size (micron) Shut-in pressure (psig) DPEH pressure setting 16 psig 16 psig PEH pressure setting 1050 psig 425 psi Sand count (history) 50 PPTB N/A Testing 6

7 New Wellhead Installations The wells selected had the following selection criteria: 150-3,700 bbld 675-2,025 psi ( 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 7

8 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 8

9 Results Other Technologies Considered 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 9

10 Close Pack Hydrocyclones HC - Wellhead 10

11 EHC vs ESI ESI EHC Recommended Min Inlet Pressure (psi) Pressure Drop (psi) 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 11

12 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. 12

13 Some of Our Customers Questions? Steve Coffee enerscopesystems.com 13