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Published byJohnathan Townsend Modified over 9 years ago
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Case History of Gas Lift Conversions in Horizontal Wells in the Williston Basin Authored by Keith Fangmeier, Terry Fredrickson, Steve Fretland, and Lee Rieger Amerada Hess Corporation
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Williston Basin South Dakota 31 Million Barrels North Dakota 1,361 Million Barrels Manitoba 212 Million Barrels Saskatchewan 1,776 Million Barrels Montana 815 Million Barrels
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Beaver Lodge Field
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Beaver Lodge Madison Unit Historical Production
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BLMU Field Map
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BLMU Reservoir Properties Permeability2.1 md Porosity9.10% Original GOR1773 scf/bo P BP 3205 psia Oil Gravity39-42 Water Salinity/Gravity287,000 ppm/1.18 Hydrogen Sulfide2.60% Reservoir Temperature 241 F
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Example Horizontal Section 25’
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BLMU Field Redevelopment Phase 1: ESP’s and GL with 2-7/8” tubing Phase 2: ESP’s with advanced gas handling equipment Phase 3: GL with 3.5” tubing Phase 4: Facility and pipeline modifications Phase 5: Future enhancements
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Phase 1. ESP’s and GL with 2-7/8” Tubing ESP’s Installed in the initial completions to recover the large fluid volumes during drilling (~40,000 bbls) Produced large fluid volumes (~3,000 BFPD) Replaced with GL ran on 2-7/8” due to continual pump failures (2 failures/well/year) Failures with consistent gas handling issues
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Example Rates after Gas Lift Conversion
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Phase 2. ESP’s with Advanced Gas Handling Equipment Installed to maximize production Utilized the new technologies from two ESP manufactures Initial installation had a favorable run life of 8 months, but subsequent installations had short run lives (< 1 month)
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Phase 3. GL with 3.5” Tubing Keeps wells online Overrides the heading issues 3.5” tubing provided more tubing capacity
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Production Tests after Conversion using 3.5” OD Tubing
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Summary of Average GVF’s Well NameWell Test Lift Type BOPDBWPDOil %MCFD FGLR (scf/bbl) PIP (psig) GVF BLMU C-05H06/01/2003ESP335239312.30%50218421756.30% BLMU C-05H06/26/2003ESP228168811.90%1093570191640.30% BLMU C-05H12/30/2003GL397261913.20%57281899 1800 est73.70% BLMU H-09H02/24/2003ESP367246013.00%34871233160766.70% BLMU H-09H12/30/2003GL558250418.20%80282622 1500 est82.50% BLMU V-27H10/01/2003ESP593223521.00%1520537238225.70% BLMU V-27H12/30/2003GL717365616.40%3565815 2000 est48.00%
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Phase 4. Facility and Pipeline Modifications Production Enhancement Install portable production facility (PPF) Removes gas at well site lowering FTP Monitor well continuously Minimizes construction time Easily removed and moved to other wells More cost effective than installing larger flowlines
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Gas Lift Pressure Chart
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Production After Installation of PPF
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Lifting Cost Summary Gas Lift: $0.72/BOE ESP: $1.31/BOE BOE = BO + (MCF/6) BOE = BO + (MCF/6)
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Inflow Performance Dual Porosity System (matrix/fracture) Difficult to predict PI increases with increasing drawdown FGLR increases with liquid production
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FLGR Response to Increased Drawdown
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Future Enhancements install 4.5” tubing (7-5/8” casing only); install annular flow with conventional gas lift pressures; and increase the gas injection pressure, with annular flow, for single point deep injection in the horizontal section.
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Nodal Analysis Comparing Annular vs. Tubular Flow
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Automation Overview SCADA system currently in place Scheduled to be replaced with a web based surveillance system New system will allow production engineers to trend Casing pressure Injection gas rate Flowline pressure Flowline temperature New system will used to better optimize production
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Conclusions The BLMU’s secondary gas cap, natural fractures, and horizontal completions create a production opportunity that is best exploited with gas lift. Gas lift is more cost effective than ESP’s in the BLMU. Inflow modeling of a naturally fractured reservoir with horizontal completions is difficult. The State of North Dakota allows an operator to produce wells at a maximum or most efficient rate. Increased drawdown permits recovery of lost drilling fluids and solids and subsequently increases GLR’s. Well performance appears to improve as a result of continuous operations. High volume lift systems require coordination between production engineering and field operations. Gas lift is essentially transparent to the problems induced by terrain slugging.
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Acknowledgments Fred Roberts of Production Services in Williston, North Dakota Amerada Hess Management Team
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