SPE Members Abstract A recently developed, environmentally safe, water-based drilling fluid has been given its first field trials. The successful field tests have shown that the fluid is indeed very shale stabilizing, has the ability to solve some mud related drilling problems, is easy to formulate and maintain, and is non-hazardous and environmentally safe. These results have corroborated the laboratory testing which had shown that the fluid stabilizes shales by the same mechanism as does oil-based muds. The drilling fluid, which is based on methylglucoside (MEG), thus has the potential to replace oil-based drilling fluids in many operational areas. The use of this drilling fluid could reduce or eliminate costly disposal of oil contaminated drilled cuttings, minimize health and safety concerns, and minimize environmental effects. Introduction Oil-based drilling fluids are used routinely in many operational areas. These applications are normally in areas where the drilling situation requires the advantages provided by the excellent performance of oil-based drilling fluids. However, in many of these areas the use of oil-based drilling fluids is cause for increasing concern due to environmental restrictions and disposal costs. Water-based drilling fluids that can give oil-mud like performance are needed for use in these situations. Any water-based replacement fluid must possess those characteristics that make the oil-based fluid a good choice for the given application. Oil-based drilling fluids can provide superb borehole stability, are highly resistant to contamination, and are stable under high temperature conditions. The use of oil-based muds also can give excellent drilling performance when used in conjunction with PDC bits. The water-based mud must replicate the performance of the oil-based fluid. A new water-based drilling fluid system has been developed that has an excellent chance of replacing oil-based muds in many applications. The fluid is based on methylglucoside (MEG). As indicated by its structure as shown in Figure 1, methylglucoside is a chemical derivative of glucose. Methylglucoside is supplied as a liquid containing 70% solids. As supplied it contains about equal portions of the alpha and beta forms of methylglucoside. P. 605

fax 01-972-952-9435. AbstractThis paper will address all of the planning and logistical issues involved with drilling the first ultra deepwater wells off the coast of Malaysia. Murphy Sabah Oil recently contracted the Diamond Offshore Ocean Baroness to drill wells in water depths ranging from 1300 m to 2000 m of water.Since a moored rig was used for the project long range planning and engineering was required to moor the rig in world record mooring depths without any boats or contractors in the area with ultra deepwater mooring experience.Well design and strategy required the initial string of conductor casing to be placed at depths exceeding 750 m below the mudline. Due to possible high pore pressures, the riserless section was designed to be drilled with water based mud. The paper will address the logistical and planning issues involved with transporting mud volumes offshore in excess of 15000 bbls in an area without deepwater logistical support. The selection and procurement of proper "deepwater" cement will also be discussed. Synthetic based mud was also a part of the drilling strategy. Since synthetic fluids had never been used before in this area, the planning phase for this fluid requirement will offer several lessons learned for industry.Well design was further complicated by an abnormally high temperature profile that brought on several well design and strategy issues.The well was also the initial project for a recently upgraded rig, which added to the complexity of the mobilization along with commissioning requirements. The rig had minimal downtime during the project.

Kikeh is Malaysia's first offshore deepwater development. Located in the South China Sea offshore the east Malaysian state of Sabah, the Kikeh oilfield lies in average water depths of 1,320 meters. With recoverable reserves in excess of 400 million barrels of oil, it is expected to achieve a plateau production rate of 120,000 barrels per day. This discovery in Block K was made in August 2002, with production initiated in August 2007. The development incorporates a Spar as well as a subsea water injection and production system that is connected to a Floating Production Storage and Offloading (FPSO) vessel. Kikeh is planned to be developed utilizing 34 wells. This paper aims to present a general overview of the Kikeh project and describe the numerous innovations that were incorporated into it. Introduction In 1999, Murphy acquired the rights to explore the deepwater Block K, offshore the eastern state of Sabah, Malaysia, as shown in Figure 1. The block encompasses an area of 4,111 km2, in water depths ranging from 1,300 m to 1,400 m.

SPE Members Abstract Texaco successfully completed three subsea wellhead tiebacks to a fixed (conventional) platform at Garden Banks Block 189 in late 1991. These three wells in 718 feet of water were the second deepest subsea wellhead tiebacks (38 feet less water depth than the present record) attempted in the world, and the deepest tiebacks ever attempted using 24" conductor pipe. In addition to involving near-record water depths, the project dealt with unprecedented misalignment conditions which could have easily jeopardized any chance of success. This paper will present a case history of the successful tieback operation for the #1, #2, and #3 wells. Introduction In November of 1988, Texaco drilled and tested its first well on Garden Banks Block 189, located in the Gulf of Mexico 185 miles southeast of Houston. A short time later, plans and construction began on a 9-slot spacer template to be installed in 718 feet of water over the discovery well (Well #1). The template was installed in May 1989 and two additional delineation wells were immediately drilled through it. Both wells were temporarily abandoned and the drilling program suspended while the project economics were reviewed. The project received full approval in September 1989. The development goal was to achieve first production in the forth quarter of 1991. This necessitated fast-tracking the engineering and construction phases of the jacket in order to eliminate one year of normal project development time. Because this was Texaco's first subsea tieback project, significant design proposals and assumptions had to be made in a short period in order to meet the project deadlines. After installation of the jacket, offset conditions were found ranging to maximums of 1.3 degrees of total angular misalignment and 20 inches of horizontal misalignment. Normal tieback equipment would have allowed for only one of the three wells to be tied back to the platform. In order to successfully tieback the two most severely misaligned wells, Texaco and Dril Quip designed and implemented a two-stage tieback system utilizing short "flex" joints of conductor pipe equipped with conventional squench-type (weight set) connections. P. 657^

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis paper describes lessons learned while selecting and utilizing a string of 5-1/2" drill pipe with special reduced clearance outside diameter (OD) tool joints in a long-term deepwater Gulf of Mexico drilling program. Actual field data including hydraulic analysis, fishing considerations, tripspeed, and completion uses are chronicled. The paper also discusses using the string of drill pipe to drill inside a 9-5/8" drilling liner along with tieback and completions inside 9-5/8" production casing. Savings associated with using one string of drill pipe are presented. Inspection results and all damages are discussed. A comparison of drilling loads, drilling hydraulics and completion hydraulics is made on this string of specialty 5-1/2" drill pipe vs. standard 5" drill pipe along with a limited comparison to 6-5/8" drill pipe. Running and handling aspects are analyzed and discussed. A specific well that utilized this string of 5-1/2" drill pipe was drilled to below 27,500' MD (25,600' TVD) and is described as the example case for the program.