Wellhead compression Multi well LP gas gathering

Transcription

1 Wellhead compression Multi well LP gas gathering With screw compressors siemens.com/answers

2 General

3 Wellhead compression What is it? Compression close to the wellhead lowers the flowing wellhead pressure, which increases production and prevents liquid loading. Siemens wellhead compressor solution can thereby substantially enhance the recovery rate. Why do I need it? Valuable hydrocarbons will not be produced Expensive field abandonment is needed soon Production obligations/ambitions can not be met New explorations necessary (high risk & investment) Siemens AG All rights reserved.

4 When do I need wellhead compression? Phase 1: Free flow, well pressure bar. No compression needed Reservoir High Pressure Xmas tree Gas Treatment Facility Transport pipeline Phase 2: Well pressure < 80 bar Reservoir Medium Pressure Xmas tree Central Compression (Restaging) Gas Treatment Facility Transport pipeline Phase 3: Well pressure < 10 bar Reservoir Low Pressure Xmas tree Wellhead compression Central Compression (Restaging) Gas Treatment Facility Transport pipeline Siemens AG All rights reserved.

5 Well life & production rate Siemens Wellhead Compression Critical flow rate Wet Well Rate MSCFD Dry Well Rate MSCFD Rate [MSCFD] Any Gas Well will flow to here Declining flow rate, well dies With Siemens Well head Compression Extra production potential Time [year] Siemens AG All rights reserved.

6 Single or multi well?

7 Main spec single and multi well compr unit Single well compr Multi well compr No of wells Min inlet pressure ~ atmospheric ~ atmospheric Max discharge pressure 30 bar 50 bar Capacity control 100%-50% 100%-15% Power ~ 35 kw 400 kw 3 MW 4 barg m3/d to m3/d Peak liquid 8 m3/d [50 bbl] m3/d [ bbl] Remark Piston compressor Gas engine combi Screw compressor (oi) E-motor

8 Application single and multi well compression unit Single well compr Multi well compr Well plot Distributed Centralised (well pad or cluster) Well size/capacity Small Medium/Large Availability/reliability Medium High (>98%) Fleet management Complex Simple Transport pressure No Yes Remark Booster station Electrification

9 Case study

10 Customer Gazprom Location West Siberia Oil injected screw compressor Power electric motor 450 kw Customer Gazprom Location West Siberia Oil injected screw compressor type Power electric motor 450 kw Capacity bara suction Discharge pressure 7-10 bara Inlet pressure 2-7 bara Remote operated Availability 95-98% Capacity PSI suction Discharge pressure PSI Inlet pressure PSI Remote operated Availability 95-98% Results 5 wells connected: 2x killed wells produce continuously 3x well immediate boost of production Results 5 wells connected: 2x killed wells produce continuously 3x well immediate boost of production TCO based on 7 years of operation: Added costs 0,01 euro / 1 mn3 Added costs 0,35 USD / 1000 CF Siemens AG All rights reserved.

11 Gazprom Wellhead compressor for mature gas field Operational back ground: Many of Gazproms natural gas assetsin West Siberia have been producing since the seventies. These depleting assets face severe production decline and liquid loading. For revitalization of their mature wells Gazprom introduced wellhead compression Customer benefits : Multi well compression (5-7 wells hooked up) gives a significant reduction of required units, site preparations and service calls. Condensate, formation water and condensed water. Unit handles slugs and high LTG ratios Package tailored to Russian rules&regulations, Gazproms engineering principles and West Siberian climate (- 55 C) Scope of supply: Siemens main contractor Complete functional unit, ready for hook up E-motor driven oil injected screw compressor Installation supervision, commissioning Service Additional remarks Capacity bara suction Capacity 8 60 PSIa In operation since summer 2011 Siemens AG All rights reserved.

12 Conceptual study

13 Workflow 1. Production modelling (sub-surface & surface) 3. TCO Economics (production profiles, cash flows) 2. Equipment (selection, sizing, pricing CAPEX/OPEX)

14 Integrated production modelling Gas Treatment Facility

15 Integrated production modelling Well cluster A consisting of 7 wells. Well inflow individually considered. Compressor in multi well operation simulated. Three compressor configurations considered: 1. Actual capacity 4300 m a3 /h Max power 300kW 2. Actual capacity 7100 m a3 /h Max power 600kW 3. Actual capacity 9500 m a3 /h Max power 900kW Assumptions: Start compression winter 2015 End compression spring 2022 Availability wells 95% Vertical wells Low intermediate/discharge pressure selected Flow data for a time window of 8 years

16 Production modelling Multi-well; Concept 600kW Time frame First day of operation Well no 1 Well no 2 Well no 3 Killed well End of time frame Well no 4 Well no 5 Well no 6 Well no 7 = No Compression = WH Compression

17 Economics Three compressor configurations considered: 1. Actual capacity 4300 m a3 /h Max power 300kW 2. Actual capacity 7100 m a3 /h Max power 600kW 3. Actual capacity 9500 m a3 /h Max power 900kW Three compressor drives considered: A. Gas engine = reciprocating motor [ = Gas ] B. E-motor; external given MW/h price [ = E ] C. E-motor; independent power generation 5 MW gas turbine [ = GT ]. Pro ratio usage. 10 concepts = 9 compression concepts + do nothing scenario

18 Economics 1 st killed well

19 Economics First day of operation Do nothing Purchase

20 Economics Cum AT cash flow 900kW PG 600kW PG 900 kw gas 300kW PG 600kW gas 600kW E 300kW E 300kW gas 900kW E

21 Economics Economic indicators 300 kw Electrical 300 kw Elec Pgen 300 kw Gas 600 kw Electrical Compression Scenario 600 kw Elec Pgen 600 kw Gas 900 kw Electrical 900 kw Elec Pgen 900 kw Gas Gas Reserves (e6m3) 512,73 512,73 437,86 628,66 628,66 536,28 682,33 681,16 573,09 Total Capital (MRUB) 158,76 184,16 203,21 190,51 234,96 247,67 209,56 279,42 266,72 Legend BT = Before Tax AT = After Tax NPV = Net Present Value ROR = Rate Of Return DPI = Discounted Profit Index BT NPV at 0% (MRUB) 587,92 653,63 546,45 593,56 768,96 646,41 549,29 795,98 673,69 BT NPV at 10% (MRUB) 272,03 307,68 232,51 249,41 359,48 276,23 204,42 361,41 283,56 BT NPV at 15% (MRUB) 182,42 208,91 143,98 152,8 242,33 171,51 108,65 237,32 173,29 AT NPV at 0% (MRUB) 463,27 514,71 425,81 466,36 604,72 503,3 430,1 624,37 524,06 AT NPV at 10% (MRUB) 204,97 231,47 168,8 184,34 268, ,84 266,87 204,25 AT NPV at 15% (MRUB) 131,96 150,92 96,6 105,47 173,19 114,56 68,48 165,28 114,24 CONFIDENTIAL Payout BT (months) 51,4 49,26 56,14 57,35 49,18 55,35 62,43 51,2 55,99 Payout AT (months) 54,04 52,19 58,78 59,66 52,36 58,15 64,3 54,37 58,8 ROR BT (%) 39,4 40,98 30,98 30,39 39,55 31,08 24,42 35,99 30,02 ROR AT (%) 34,33 35,37 26,79 26, ,78 21,71 30,81 25,88 DPI BT at 0% 3,7 3,55 2,69 3,12 3,27 2,61 2,62 2,85 2,53 DPI BT at 10% 1,93 1,88 1,29 1,47 1,72 1,26 1,1 1,46 1,2 DPI BT at 15% 1,37 1,35 0,84 0,95 1,23 0,82 0,62 1,01 0,77 DPI AT at 0% 2,92 2,79 2,1 2,45 2,57 2,03 2,05 2,23 1,96 DPI AT at 10% 1,45 1,41 0,93 1,09 1,29 0,91 0,79 1,07 0,86 DPI AT at 15% 0,99 0,97 0,56 0,66 0,88 0,55 0,39 0,7 0,51

22 Questions?