BP's digital oilfield initiative, the Field of the Future Technology Flagship, has been developing and deploying distinctive operational capabilities since it's inception in 2005. This paper describes the growing track record of value delivery, achieved through pace and scale deployment. These capabilities, which continue to be developed, support a relentless drive for continuous improvement in our asset operations, aiming at delivery of significant production (100mboed BPnet) and reserve (1bnbbl) targets by 2017. We report significant progress toward meeting these targets and highlight new key lessons from our growing body of experience.The Field of the Future concept is now a routine part of how BP builds projects and operates fields across much of our portfolio. It impacts a significant and growing proportion of net production and routinely supports >80% of our top 100 wells. A range of monitoring, analytical, optimization and collaborative solutions are applied according to asset needs and value opportunities.The in-house solutions have delivered over a third of the production target so far -ahead of plan. When integrated with general bought-in solutions, base infrastructure and collaboration benefits, we are routinely adding more than 50mboed gross production per annum.The Paper presents examples of the variety of capability, technology and solution applications that have underpinned this continuing successful value delivery.Key to this success has been:• Establishing an effective, balanced approach to R&D, deployment and value realization;• Developing clear linkage to business needs and functional priorities as a basis for effectively engaging the customer.Areas of continuing challenge include:• Sustaining uptake and usage when faced with issues and barriers arising from technical, business and organizational diversity in the asset portfolio; • Competing or aligning with other business priorities and initiatives, especially in a cost challenged environment.Looking forward, the common challenge all operators face is firmly on making it an industry-wide reality, and to fully embed "intelligent energy" in all that we build and operate.

Real time data provides key information that can be used to monitor oil and gas wells to maintain well integrity and avoid costly failures. Integrity management is at the heart of BP's operating philosophy. The company uses new technologies enabled by real time data to allow continuous improvement in well integrity management.The use of real time rate calculations has provided technical assurance to maximize production within BP's deepwater subsea field development. Production has been increased by 10,000 stb/D while maintaining well integrity and process safety assurance within safe engineering operating limits. Similarly, the Na Kika fields apply advanced flux based tools and sand alarming capabilities to protect wells from sand completion failure. Additional fields are currently using BP proprietary technology to monitor and proactively alarm on wellhead annulus pressures, successfully mitigating the well integrity risk of collapsed tubing.Well integrity management is critical for any operating company. In deep water environments where subsea well costs can exceed 100 million dollars, loss of well integrity can have serious consequences associated with production capability, loss of containment, reputational damage, and regulatory license to operate. Application of new technologies is transforming simplistic past practices into highly sophisticated automated monitoring and advanced control mechanisms enabled by real time data. These technologies have a vital role in delivering advanced capabilities so that engineers can make better decisions, faster, to help retain long term value. This paper, through case studies, will demonstrate the ability to use innovative workflows and technologies, enabled by real time data, to identify and mitigate well integrity risks. Key risks such as annulus leaks, sand control failures, and mechanical failures are monitored using Field of the Future technologies. These examples from different operating areas of BP will demonstrate continuous improvement, showing how engineers use these technologies to maintain well integrity.

Summary In this article we describe the key planning and operational experiences gained during the perforation and completion phases of the world record step-out extended reach well at the Wytch Farm oilfield in Dorset, England. We present an overview of how the M-11 well was completed successfully and describe how a combination of existing and new technology was applied to achieve Wytch Farm's most prolific producer. Well 1M-11SPy (M-11) the world record for the highest horizontal departure, 10 114 m, at any vertical depth, and a record departure to true vertical depth ratio of 6.24. The Wytch Farm extended reach wells are completed with cemented, perforated liners and electrical submersible pumps (ESP's). A new technique for perforating the well was developed to maximize inflow efficiency. This technique enables underbalance perforating without any subsequent requirement for a well kill. The impact of these improvements on completion efficiency is discussed, along with associated operational issues. The large departure required the ESP to be set at 8625 m, another world record, with the 1,000 HP motor requiring a new 7 kV cable system and a 1500 kVA variable speed controller (VSC) at the surface. We describe the VSC selection and the physical testing of the complete ESP/cable/VSC system, which was conducted before installation to ensure that sufficient torque could be generated at the ESP for a range of startup and operating conditions and to configure the new type of VSC used for optimal system performance. We also report the experience gained and review the lessons learned. Introduction The Wytch Farm development is located in an unusually sensitive environmental area on the southern coast of England. The main Sherwood sandstone reservoir lies under Poole Harbour and extends offshore under Poole Bay (Fig. 1). The Sherwood is a Triassic sandstone with the reservoir top at 1585 m true vertical depth (TVD) subsea with a maximum 110 m column of oil-bearing sand above the oil/water contact. Approximately 90% of the field total reserve basis is contained within the Sherwood reservoir. Nearly one half of the Sherwood's 430 million barrel reserves lies in the offshore extension. During 1991, advances in drilling technology enabled offshore recovery to be considered as the preferred option, utilizing extended reach wells drilled from existing offshore facilities. Since the start of extended reach drilling (ERD) in 1993, 15 ERD wells have been drilled with stepouts ranging from 3800 m up to the record breaking result of 10 114 m for well M-11. The geoscience planning, drilling, and completion of Wytch Farm ERD wells have been extensively documented. The field is now in a mature development stage and was producing approximately 100 thousand BOPD. Background Drilling Summary. Figs. 2 and 3 show the final well trajectory. A 9 5/8 in. casing was set just above the Sherwood reservoir top, which allowed 8 1/2 in. drilling of the reservoir. After drilling approximately an 800 m horizontal section into the reservoir, it was apparent that the wellbore was high within the structure, and had insufficient permeability thickness (kh) to achieve the well objectives (M-11z). At this point, it was decided to abandon this wellbore and perform an openhole sidetrack (M-11y). The sidetrack was completed successfully in the openhole section just below the 9 5/8 in. casing shoe and wellbore and drilled to its record-setting horizontal departure and total depth. The hole was then lined and cemented. Well Performance. Prolific productivity indices (PI's) for the project, up to 135 B/D/psi, have been achieved, of which M-11 realized a PI of 45 B/D/psi. As discussed in detail later, these high productivities, coupled with relatively low reservoir pressures, have pushed ESP technology to the technical limits in terms of capacity and power requirements. In addition, the inability to effectively interpret pressure-transient test data has resulted in uncertainty in determining precise completion efficiency and PI potential estimates. Perforating and Workover Operational Histories. The conventional tubing conveyed perforating (TCP) underbalanced shoot, kill pill, and test string recovery method has previously been adopted as the preferred completion technique. Key issues of the deployment technique, charge design criteria for debris, and kill pill formula were engineered to minimize formation damage and maximize productivity. In addition, workover operations have traditionally relied on pumping viscous, fibrous lost circulation material (LCM) kill pills that were perceived to be nondamaging to attain well control. Current production logging tool (PLT) information has indicated that select production intervals are not contributing to production. There is no obvious reason for this selective productivity other than that the intervals may be plugged with residual LCM. Because of the operational complexity and associated high costs to attain PLT data, baseline data are not readily available to distinguish between formation damage from the initial perforating vs. subsequent workover operations. With production depletion and known decreases to static reservoir pressure, the recent risk of kill pill formation damage has increased because of greater applied overbalances in combination with less available production underbalance. ESP and Drive Summary. The three different types of VSC's that Wytch Farm uses to control ESP systems are a variable voltage source quasisquare wave, a current source, and a constant voltage source pulse width modulated (PWM).

Real time data provides key information that can be used to monitor oil and gas wells to maintain well integrity and avoid costly failures. Integrity management is at the heart of BP's operating philosophy. The company uses new technologies enabled by real time data to allow continuous improvement in well integrity management.The use of real time rate calculations has provided technical assurance to maximize production within BP's deepwater subsea field development. Production has been increased by 10,000 stb/D while maintaining well integrity and process safety assurance within safe engineering operating limits. Similarly, the Na Kika fields apply advanced flux based tools and sand alarming capabilities to protect wells from sand completion failure. Additional fields are currently using BP proprietary technology to monitor and proactively alarm on wellhead annulus pressures, successfully mitigating the well integrity risk of collapsed tubing.Well integrity management is critical for any operating company. In deep water environments where subsea well costs can exceed 100 million dollars, loss of well integrity can have serious consequences associated with production capability, loss of containment, reputational damage, and regulatory license to operate. Application of new technologies is transforming simplistic past practices into highly sophisticated automated monitoring and advanced control mechanisms enabled by real time data. These technologies have a vital role in delivering advanced capabilities so that engineers can make better decisions, faster, to help retain long term value. This paper, through case studies, will demonstrate the ability to use innovative workflows and technologies, enabled by real time data, to identify and mitigate well integrity risks. Key risks such as annulus leaks, sand control failures, and mechanical failures are monitored using Field of the Future technologies. These examples from different operating areas of BP will demonstrate continuous improvement, showing how engineers use these technologies to maintain well integrity.

This paper describes the key planning and operational experiences gained during the perforation and completion phase of the world record step-out extended reach well at the Wytch Farm oilfield in Dorset, England. The paper presents an overview of how the M- 11 well was successfully completed and describes how a combination of existing technology and new technology has been applied to achieve Wytch Farm's most prolific producer to date. Well 1M-11SPy (M-11) holds the world record for the highest horizontal departure, 10114m, at any vertical depth, and a record departure: to true vertical depth (TVD) ratio of 6.24. The Wytch Farm extended reach wells are completed with cemented, perforated liners and electrical submersible pumps (ESPs). A new technique for perforating the well was developed to maximise inflow efficiency. This technique enables underbalance perforating without any subsequent requirement for a well kill. The impact of these improvements on completion efficiency is discussed, along with the associated operational issues. The large departure required the ESP to be set at 8625m, another world record, with the 1000 HP motor requiring a new 7kV cable system and a 1500 kVA variable speed controller (VSC) at surface. This paper describes the background of VSC selection and the physical testing of the complete ESP/cable/VSC system that was conducted prior to installation to ensure that sufficient torque could be generated at the ESP for a range of start-up and operating conditions, and to configure the new type of VSC used for optimal system performance. The paper reports experience gained, and reviews lessons learned. P. 579