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Directional-Drilling Sidetrack:A-6 AH:7315 to 8348 m.The well path was followed as planned,with a maximum DLS of 5.7°/30 m in the kickoff section and 68° inclination throughout the Draupne formation.It was found that the Draupne formation had collapsed for the second time when attempting to run in hole with the new BHA,and a decision was made to perform a second sidetrack on cement below the 103/4-in.Shoe instead of risking stuck pipe in this unstable formation.
Directional-Drilling Main Section:A-6 AHT2:7300 to 9082 m.The Draupne formation was drilled with 65°inclination approximately 100 m away from the other well penetration points and the fault zone.The dip log showed that the relative angle between the formation and the well was good,with an average of 17°.The 1782-m section was drilled in one run as planned with a maximum DLS of 5.87°/30 m and 65°inclination across the Draupne,which was enough to keep the formation stable.The primary objectives of the well were fulfilled,and the TD of the well was set.
7-in.Liner.The 7-in.29-lbm/ft liner was run successfully to 9080 m MD.Generally,low friction was experienced while running in,matching a friction factor trend of 0.10 and 0.25 for casing and open hole,respectively.The running string consisted of approximately 2000 m of 51/2-in.HWDP above the 7-in.liner and 57/8-in.DP to surface.Restrictions were encountered at 7924 to 7950 m and at 8670 m,and rotation was established to run the liner through the restrictions.The 7-in.liner was set in place and cemented.
Subsea Cuttings Injection The well was prepared for cuttings injection in the annulus between the 20-in.and 133/8-in.casing.The well was fractured,and the annulus was displaced with treated seawater.A stable injection rate of 1000 L/min was achieved with a surface pressure of 90 bar.The formation below the 20-in.shoe at 1361 m MD is fractured upward to the shallower Utsira sand formation at 1000 to 1100 m.The plan is that cuttings and slop from subsequent wells will be injected into this formation.Before this well,the Visund field had only one operating cuttings injector,so it was important to have a backup cuttings-injection well.
Downhole Instrumentation and Control System (DIACS) Completion
A cleanout string was run to TD to scrape the casing wall and ensure free passage of the perforation guns.At TD,the well was displaced from oil-based mud to potassium formate brine and a kill pill by use of a wash train and seawater.The updated formation-pressure MWD data allowed the use of this brine.The string contained an alternating circulation tool to increase the rate in the 103/4-in.casing during mud conditioning and circulation of the wash train.This addition enhanced the cleanout operation considerably.
Directional-Drilling Sidetrack:A-6 AH:7315 to 8348 m.The well path was followed as planned,with a maximum DLS of 5.7°/30 m in the kickoff section and 68° inclination throughout the Draupne formation.It was found that the Draupne formation had collapsed for the second time when attempting to run in hole with the new BHA,and a decision was made to perform a second sidetrack on cement below the 103/4-in.Shoe instead of risking stuck pipe in this unstable formation.
Directional-Drilling Main Section:A-6 AHT2:7300 to 9082 m.The Draupne formation was drilled with 65°inclination approximately 100 m away from the other well penetration points and the fault zone.The dip log showed that the relative angle between the formation and the well was good,with an average of 17°.The 1782-m section was drilled in one run as planned with a maximum DLS of 5.87°/30 m and 65°inclination across the Draupne,which was enough to keep the formation stable.The primary objectives of the well were fulfilled,and the TD of the well was set.
7-in.Liner.The 7-in.29-lbm/ft liner was run successfully to 9080 m MD.Generally,low friction was experienced while running in,matching a friction factor trend of 0.10 and 0.25 for casing and open hole,respectively.The running string consisted of approximately 2000 m of 51/2-in.HWDP above the 7-in.liner and 57/8-in.DP to surface.Restrictions were encountered at 7924 to 7950 m and at 8670 m,and rotation was established to run the liner through the restrictions.The 7-in.liner was set in place and cemented.
Subsea Cuttings Injection The well was prepared for cuttings injection in the annulus between the 20-in.and 133/8-in.casing.The well was fractured,and the annulus was displaced with treated seawater.A stable injection rate of 1000 L/min was achieved with a surface pressure of 90 bar.The formation below the 20-in.shoe at 1361 m MD is fractured upward to the shallower Utsira sand formation at 1000 to 1100 m.The plan is that cuttings and slop from subsequent wells will be injected into this formation.Before this well,the Visund field had only one operating cuttings injector,so it was important to have a backup cuttings-injection well.
Downhole Instrumentation and Control System (DIACS) Completion
A cleanout string was run to TD to scrape the casing wall and ensure free passage of the perforation guns.At TD,the well was displaced from oil-based mud to potassium formate brine and a kill pill by use of a wash train and seawater.The updated formation-pressure MWD data allowed the use of this brine.The string contained an alternating circulation tool to increase the rate in the 103/4-in.casing during mud conditioning and circulation of the wash train.This addition enhanced the cleanout operation considerably.
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