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1
Proceedings Papers
Publisher: Society of Petroleum Engineers (SPE)
Paper presented at the SPE International Symposium and Exhibition on Formation Damage Control, February 26–28, 2014
Paper Number: SPE-168118-MS
... the fields with the smallest well count possible. The results from this study could prove useful to production and completion teams supporting large gas field developments. This paper presents a study to determine the feasibility of a subsea sand control gas well producing at rates up to 500 MMscf/D...
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Published: 31 October 2022
Figure 17 Gas production reduction from 45 MMscf/D to 10 MMscf/D following workover of 12 OH horizontal wells with cemented liners More
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Published: 25 October 2020
Figure 8 Results of Example 1,G 1 = 1,000 MMscf and 2,000 MMscf More
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Published: 25 October 2020
Figure 9 Results of Example 1, q i2 = 0.4 MMscf/d and 0.8 MMscf/d More
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Published: 23 March 1998
Fig. 3 Comparison of actual production of 183 MMscf, production of 206 MMscf predicted by ANN, and potential production of 396 MMscf predicted by ANN for four new, infield wells. More
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Published: 05 October 2003
Fig. 23 Restart to 600 MMscf/D From 150 MMscf/D Before Shutdown - 2-20/24 in. lines More
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Published: 05 October 2003
Fig. 24 Restart to 600 MMscf/D From 300 MMscf/D Before Shutdown - 2-20/24 in. lines More
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Published: 05 October 2003
Fig. 25 Restart to 600 MMscf/D From 450 MMscf/D Before Shutdown - 2-20/24 in. lines More
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Published: 05 October 2003
Fig. 26 Restart to 600 MMscf/D From 400 MMscf/D Before Shutdown - 2-20/36 in. lines More
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Published: 05 October 2003
Fig. 27 Restart to 600 MMscf/D From 600 MMscf/D Before Shutdown - 2-20/36 in. lines More
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Published: 15 April 2007
FIGURE 4 CASE A, PIGGING AT 90 MMscf/D AND 450 MMscf/D FROM EXISTING FLOWLINE More
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Published: 15 April 2007
FIGURE 5 CASE B, PIGGING AT 180 MMscf/D AND 450 MMscf/D FROM EXISTING FLOWLINE More
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Published: 15 April 2007
FIGURE 6 CASE C, PIGGING AT 540 MMscf/D AND 450 MMscf/D FROM EXISTING FLOWLINE More
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Published: 15 April 2007
FIGURE 7 CASE D, START UP FROM 0 TO 720 MMscf/D IN 8 HOURS AND 450 MMscf/D FROM EXISTING FLOWLINE - WITHOUT LEVEL CONTROLLER More
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Published: 15 April 2007
FIGURE 8 CASE D, START UP FROM 0 TO 720 MMscf/D IN 8 HOURS AND 450 MMscf/D FROM EXISTING FLOWLINE - PI LEVEL CONTROLLER More
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Published: 15 April 2007
FIGURE 9 CASE D, START UP FROM 0 TO 720 MMscf/D IN 8 HOURS AND 450 MMscf/D FROM EXISTING FLOWLINE - PI LEVEL CONTROLLER - MAXIMUM LIQUID DRAIN FLOWRATE SLOPE=4000 (bbl/D)/hr More
Images
Published: 15 April 2007
FIGURE 10 CASE D, START UP FROM 0 TO 720 MMscf/D IN 8 HOURS AND 450 MMscf/D FROM EXISTING FLOWLINE - PI LEVEL CONTROLLER - MAXIMUM LIQUID DRAIN FLOWRATE SLOPE = 4000 (bbl/D)/hr - MAXIMUM LIQUID DRAIN FLOWRATE = 62000 More
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Published: 11 June 2018
Figure 10 Production Rate [MMscf/day] and Cumulative Recoverable Gas [MMscf] for (a) Haynesville (b) Marcellus (c) Barnett for the Well Life (5043 days) More
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Published: 11 June 2018
Figure 13 Production Rate [MMscf/day] and Cumulative Recoverable Gas [MMscf] for Haynesville (SVR2) changing (a) Matrix Permeability (b) Fracture Half - Length (c) Fracture Density More
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Published: 11 June 2018
Figure 16 Production Rate [MMscf/day] and Cumulative Recoverable Gas [MMscf] for Marcellus (SVR2) changing (a) Matrix Permeability (b) Fracture Half - Length (c) Fracture Density More
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