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Drillpipe for Shale Plays - Requirements, Considerations and Lessons Learned
Jellison, Michael (NOV Grant Prideco) | Brock, Jim (NOV Grant Prideco) | Muradov, Andrei (NOV Grant Prideco) | Morgan, Dan (NOV Grant Prideco) | Rowell, Jim (Premium Oilfield Services)
Abstract Shale drilling for both natural gas and hydrocarbon liquids has increased dramatically in North America over the last several years. Shale oil and gas deposits are known to exist all over the globe including Australia and the rest of the Asia Pacific. This paper discusses the requirements for drillpipe in shale drilling applications along with a review of some of the challenges and problems associated with the drillstring in these critical applications. Most wells are horizontal with long departures. Typical wells in the Balkan Shale are 17,000 ft MD, 11,000 ft TVD with a 6,000 ft horizontal reach. Drilling these wells puts huge demands on the drillpipe and rotary shoulder connections and pushes the drilling equipment and rig crews beyond the requirements of typical onshore well construction projects. Many, if not most, of the shale wells require advanced design, double shoulder connections (DSC) on the drillstring to provide the enhanced torsional strength and streamlined connection dimensions required to effectively drill these prospects. The paper presents connection design solutions along with considerations for safe and efficient running procedures. Although, the advanced DSCs are designed to be transparent to normal drilling operations, compared to standard API connections, some problems have been encountered. The paper addresses these running and handling issues and provides guidelines to mitigate these problems. Excessive tool joint and drillpipe body wear have also been encountered in several shale plays. This is discussed, along with recommendations to limit wear. Stick-slip has created drillstring problems on several wells. Stick-slip can cause damage to the drillpipe and, in the extreme, downhole connection back-offs have occurred. The paper looks at aspects of case histories to illustrate these issues and provides lessons learned to improve shale drilling operations in North America, the Asia Pacific and other regions of the world.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (1.00)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- (12 more...)
- Well Drilling > Drillstring Design > Drill pipe selection (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale oil (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Management > Energy Economics > Unconventional resource economics (1.00)
Abstract As the severity of sour drilling applications has increased, the requirement for drill stem materials resistant to sulfide stress cracking (SSC) has accelerated. Sour service drillpipe, traditionally manufactured with SSC resistant upset tubulars and tool joints, has been available for some time. Sour Service drillpipe metallurgy is not specifically controlled by NACE MR 0175/ISO 15156,1 however these tubulars and tool joints are often evaluated in accordance with the standard. The friction welds joining the upset tubulars and tool joints were not resistant to SSC and were not evaluated. This has been acceptable for many sour drilling applications since the weld is not the mostly highly stressed region of the drillpipe joint and because the operator has a certain degree of control over the environment through the drilling fluid properties and additives. As more severe environments with higher Hydrogen Sulfide (H2S) concentrations were identified for exploration and development, it became apparent that a fully SSC resistant drillpipe system including the friction welds was necessary. This paper presents the successful development and qualification of SSC resistant friction welds for critical sour applications. It describes the engineering and manufacturing philosophy employed, laboratory testing procedures with results presented and applications for the SSC resistant drillpipe. Since NACE MR 0175/ISO 15156 does not address friction welds the engineering team developed unique and innovative criteria together with testing procedures for the new weld technology. A new patent pending four-point bending test procedure and fixture were developed that employed unpolished samples that represent the surface finish of the product in service, in contrast to the polished samples used in NACE TM0177 testing. This paper provides background information on the evolution of sour service drillpipe and reviews case histories where sour service drillpipe has been successfully used including the new pipe with SSC resistant friction welds. The paper can benefit drilling engineers involved in critical sour drilling operations.
- South America > Brazil (0.30)
- North America > United States (0.28)
Successful Implementation of Latest Generation of Double Shoulder Connection Technology in Fast Slimhole Drilling - A Review after Broad Adoption in the Gulf of Thailand
Plessis, Guillaume (NOV Grant Prideco) | Brock, Jim (NOV Grant Prideco) | Wood, Jeff (Chevron Thailand Exploration and Production)
Abstract In 2010, Chevron Thailand successfully conducted a unique comparative field test involving two strings of drill pipe, one featuring a new 3 generation double shoulder connection (3 Gen DSC) against another with the previous generation connection (2 Gen DSC). Both strings were used to drill off the same offshore platform with all parameters being equal besides the drill pipe connection selection. This test was required to gauge a possible solution to the operator's need for higher drilling torque in the challenging fast rotary drilling of the slimhole production interval. The evaluated 3 Gen DSC was originally developed and introduced to allow drilling always more challenging wells. It was designed to achieve a set of performances, which exceed the capability of the successful 2 Gen DSC for torque and hydraulics with an enhanced fatigue resistance. One of the particular design priorities was to allow for fast makeup and breakout through the use of a new feature to drill pipe; a double start thread. Results of this field trial were gathered in a previous paper that shows actual time saving in running speed, which is of interest to Chevron, initial trend seen in the lower number of connection needing repairs and evaluation of the cost saving for adopting the new technology on all rigs drilling for the operator. Based on this initial set of data, Chevron decided to switch to the 3 Gen DSC for the 4 in. drill pipe used in slimhole drilling. This new paper will briefly summarize the result of previously presented material but will focus on the actual field experience with the new technology deployed on three drilling rigs for more than six months now. Special emphasis will be put on evaluating the connection ruggedness through results found in the inspection of the equipment, which was hard to evaluate on the initial short time trial.
- Research Report > New Finding (0.34)
- Research Report > Experimental Study (0.34)
- Well Drilling > Drillstring Design > Drill pipe selection (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Equipment (1.00)
Innovative Tubular, Hoisting, and Deepwater Rig Designs Extend Hook Load Envelope to 2,000,000 Pounds
Brock, J. N. (NOV Grant Prideco) | Chandler, R. Brett (NOV Grant Prideco) | Selen, C.. (Maersk Drilling USA) | Dugas, J.. (Quail Tools) | White, W.. (Quail Tools) | Vasquez, M.. (Statoil) | Jonnalagadda, A.. (Statoil)
Abstract In March of 2010, a hook load world record was set on Statoil’s Tucker well in the Gulf of Mexico Walker Ridge Block 543, Well Number 1. A string of 14-inch by 13-5/8-inch casing was landed with a total hook load of over 1,960,000 pounds. The casing string was successfully set to 24,893 MD (24,490 TVD) feet in 6,700 feet of water. With water depths increasing to over 10,000 feet, well depths exceeding 35,000 feet and extended reach targets pushing out over 37,000 feet MD, the worldwide drilling envelop is continually expanding. Operators are deepening the setting depths of larger diameter and heavier casing strings. Maersk Drilling’s new semisubmersible, MÆRSK DEVELOPER, optimized for field development work, designed to be cost effective and capable of drilling 40,000 foot wells in up to 10,000 feet water depth was utilized. The rig is substantially larger and more sophisticated than existing rigs operating in this segment and incorporates a number of innovative features. This case study details the record-setting casing landing operation including planning, preparation, and load path verification. The paper also documents the design, development, manufacture and deployment of the 2-million pound slip-based landing string that was required for this operation. The 6-5/8-inch, heavy wall, 150-ksi yield strength pipe incorporates an innovative thick-walled section in the slip contact area for resistance to slip-crushing loads and a uniquely designed dual-diameter tool joint to increase elevator capacity. Utilizing conventional elevator and slips, the landing string requires only conventional rig-up and operating procedures. Operational savings are realized from the faster makeup and use of standard rig equipment. Additionally, familiar operating procedures promote safe operations and limit accidents.
- Well Drilling > Drillstring Design > Drill pipe selection (0.90)
- Well Drilling > Drilling Operations > Running and setting casing (0.88)
- Well Drilling > Casing and Cementing > Casing design (0.72)