To efficiently develop reserves in the Norwegian North Sea, the operator must drill a challenging 12¼" directional borehole through a Chalk formation with high stick-slip potential. In Gaupe North, a negative vertical section was required in the initial kickoff to properly line up the well path before entering the reservoir target. The reservoir is comprised of channel/sheet sandstones interbedded with shale sequences with different pressure regimes and nearby reservoir depletion issues. The 8½" wellbore must penetrate an unstable organic shale just above the reservoir, infamous for causing hole stability problems and stuck pipe events. The regulatory agency requires this shale to be drilled in an 8½" section, requiring long exposure time, which increases risk for hole problems when running the production liner. The objective was to efficiently drill these trouble-zones and deliver two horizontal producers in a cost effective manner using an integrated engineering solution.To achieve the objective, a sophisticated multidisciplinary approach was employed including: bit/BHA offset analysis to reduce stick-slip in the chalk; BHA/RSS and drilling fluids modeling/planning; and drilling parameter plots to identify optimum RPM/WOB. Also, a real-time parameter analysis system was deployed to optimize ROP without compromising hole cleaning or well integrity.The synergy provided by a fully integrated service provider increased drilling performance and was a major contributor to the success of the Gaupe wells performance. Well 6/3-A-1H broke the previous Rushmore index for subsea development wells in the region and set a Norwegian record for wells in this class. Both wells (15/12-E-1H & 6/3-A-1H) achieved positive P10 curves and saved a total of 18 days vs AFE. Compared to an analogous UK North Sea field, significant increases in ROP were achieved resulting in the wells being drilled 20+ days faster than benchmark. The average increases in ROP for the two Gaupe wells were approximately 146%, 47% and 148% in the 17½", 12¼" and 8½" sections respectively.

When the operator embarked on an intermittent 5 well exploration, appraisal and development campaign offshore Norway between 2009 and 2012 using the West Alpha there were many challenges. The rig contract was part of a multi company consortium, the well program was varied, a 3 rd generation semi submersible rig was being used and all inclusive operating rates were high at around $1,000,000 per day.Following and expanding upon the management principles previously employed 1 , the lead operator identified an opportunity to leverage the consortium program and develop a strong relationship with the service companies, in particular the rig contractor.Health, Safety, Security and Environment (HSSE) was a key driver and over 1000 rig days were delivered without a Lost Time Incident (LTI). The lead operator was able to harmonise and standardise procedures used on every well, regardless of who operated the rig. This enabled a much clearer and more consistent message to be delivered to the work environment. This paper will outline the management process taken by the operator and contractor that enabled the following performance to be delivered: 1000 days LTI free rig operations. Record setting drilling performance with improvements up to 40%. No damage to the environment. This paper will also describe how the principles have been transferred to other parts of the operators & contractors organisations.

This paper will outline how a long term relationship between a contractor and operator that integrates their safety cultures, provides incentives to the parties, and looks for ways to continually improve performance can lead to results that benefit both parties. British Gas (BG) began an exploration program in the West Delta Deep Marine concession offshore Egypt in 1998, and hired the Atwood Oceanics rig Atwood Eagle to drill this initial program. The early exploration program was a success, and led to an exploration, appraisal and development program lasting 4.5 years and consisting of 36 wells drilled and eight wells completed with Atwood Oceanics rigs. The Atwood Eagle drilled 19 wells, the Atwood Southern Cross one, and the Atwood Hunter drilled 16 and completed eight wells. HS&E performance was held in the forefront of the planning and execution of this program, and approximately 1.5 million man hours of rig operations were accomplished without a lost time incident (LTI). Details of how the safety cultures of the companies were seamlessly integrated will be discussed. Also, as part of the drive to improve performance, BG's Total Value Drilling (TVD) initiative was executed for the Scarab Saffron eight-well completion program, the culmination of the entire rig campaign. The teamwork approach to operational improvement gained through the TVD process will be outlined. The cooperation between Atwood Oceanics and BG led to excellent results that included:A combined 1.5 million man hours achieved with three rigs on contract with BG, Rashpetco and Burullus (BG companies) in a challenging deep water drilling and completion environment.Drilling the first deep water exploration well in the area. The campaign included wells in water depths up to 3,430 feet.Best in class drilling performance compared to other operations in the area over 4.5 years without compromising safety.Operations that approached or surpassed the expected technical limit.Hiring and training of local employees into a world class safety program.No damage to the environment