American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc. This paper was prepared for International Symposium on Oilfield Chemistry of the Society of Petroleum Engineers of AIME, to be held in Dallas, Texas, Jan. 16–17, 1975. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines. Abstract A procedure for the quantitative measurement of hydrogen flux through metal membranes is described Environments similar to those found in petroleum production and process operations were used for hydrogen process operations were used for hydrogen generation. Application of this technique is directed to both the performance evaluation of various inhibitor formulations and elucidation of the mechanism of inhibition. Introduction The problem of hydrogen penetration into materials utilized in petroleum production antiprocess operations has plagued production antiprocess operations has plagued this industry for a significant number of years. Damage is normally characterized by blistering or embrittlement depending on the strength level of the particular steel in question. Hydrogen activity in systems susceptible to such attack is normally monitored in plant by pressure sensing probes described by Bonner et al. Protection is generally attained by Protection is generally attained by metallurgical design consideration, control of system chemical parameters or addition of inhibitor formulations. This study is concerned primarily with the last method mentioned and is directed to the design of laboratory test procedures for evaluating permeation inhibitors under various permeation inhibitors under various simulated operational environments. Background Metallurgy susceptible to damage by hydrogen penetration can be found in both modern day crude oil production and refining operations. Chemical environments necessary for promotion of this phenomenon are common in such processes as hydrodesulfurization and petroleum production from hydrogen sulfide bearing formations. Material failure is normally evidenced by blistering or embrittlement, in steel above Rockwell C-22 hardness. Chemical parameters monitored in addition to sulfide are parameters monitored in addition to sulfide are ammonia and cyanide. Together these three species can comprise the most hostile of permeation environments. permeation environments. If one considers the corrosion of iron by hydrogen sulfide alone, a protective film of iron sulfide, FeS, is usually formed causing the corrosion reaction to abate after a short period. The presence of cyanide, however, at levels of several hundred parts per million facilitate removal of this per million facilitate removal of this protective film by formation of a soluble protective film by formation of a soluble ferrocyanide complex, Fe(CN)6-4.
Summary BP and Maersk Drilling entered into a unique collaborative arrangement in early 2013 to develop the design for a deepwater drilling rig that is specifically aimed at conducting operations on wells with greater than 15,000 psi pressures. This paper describes how this collaborative effort was conducted. Operator and contractor each contributed expertise and information to the project and defined a joint vision of transforming how functional requirements are set and how the design of this rig would be developed. A set of relationship principles was agreed and a joint project team was formed in Houston with engineering support from contrator's technical organization in Copenhagen. An executive committee, with senior leadership from each organization, was established to provide guidance, challenge and governance. To start the design process, workflow during the well construction process was layered on top of the foundational requirements of operator's prospect inventory. Starting with a cleaner sheet of paper, the integrated team's conversations focused on inherently safer design and improving operability, efficiency, maintainability and reliability. The initial focus was on innovation and possibilities before driving toward agreement on the functional specification and rig design. The team strove to address challenges faced in the deepwater drilling industry today, at the same time continually testing their ideas for benefit. After more definition work, the opportunities were run through a detailed evaluation model to inform selection of design features and potential equipment suppliers. Major equipment suppliers and operator service companies have assisted with the development of rig functional requirements and the shipyard specification. Operator and contractor contributed their learning from previous rig builds, intakes and operation including five and ten year re-certifications into the design. Supplier selection for long lead technology development and qualification of equipment commenced in 2013 and is expected to culminate with a yard selection in 2015. As a result of this collaboration, operator and contractor better understand the needs and drivers of each other's business and have leveraged this knowledge into a more effective working relationship. Significant work remains to construct the rig and deliver it into operation. However, there is a strong belief this next generation deepwater drilling rig will provide enhanced capability, performance and value to both operator and contractor.
SPE Members Abstract This paper summarizes the planning and drilling of the North Padre Island (NPI) 960-L No. 1 well. This well was drilled to 24,938-ft. RKB offshore South Texas. The well experienced temperatures in excess of 420 deg. F and pressures above 23,000 psi at total depth. In addition, several other aspects of the well were unique to offshore drilling operations including:Development of a 2,000 kips static hook load offshore rig.Use of newly-developed 30 in, 3,000 psi ram type BOP.Drilling of deep large diameter holes (24-in. to 1,897-ft. RKB, 16-1/2-in. to 15,863-ft. RKB).Designing, testing, running, and cementing of heavy weight casing strings up to 2,110 kips air weight. Land and Geological ARCO Oil and Gas Company acquired thirty-seven (37) Offshore State of Texas Leases in three (3) separate Lease Sales. The units were pooled in October 1982 to form the 43,000+ acre ARCO Oil and Gas Company Monster Prospect. This unit was located approximately five (5) miles offshore Kenedy County Texas as shown in Figure 1. Water depths in the unit varied from +/- 63-ft. to +/- 85-ft. The prospect was located in a downdip stratigraphic portion of the productive Oligocene age Frio trend. The well objective was a very large downthrown Oligocene age Middle Frio anticlinal rollover structure which covered approximately 23,700 acres at a depth of 22,000-ft. (refer to Figure 2). Above the 22,000-ft. level the anticlinal structure was virtually nonexistent. To reach the objective, the well drilled through 9,000-ft. of very sandy Miocene age section and 3,000-ft. of shaly Oligocene age Anahuac Formation before encountering the top of the sandy Oligocene age Upper Frio Formation at 12,000-ft. RKB At 22,000-ft. RKB, the well penetrated the Oligocene age Middle Frio structural objective and encountered reservoir quality sands. Minor gas shows were seen at the structural objective below 23,000-ft. RKB, however economic quantities of hydrocarbons were not present. Planning for the ARCO Oil and Gas Company NPI 960-L No. 1 well was started in March 1982 with the initial proposed total depth of 23,000-ft. The well was spudded April 16, 1985 and reached total depth in 395 days as shown in Figure 3. The purpose of this paper is to present an overview of the drilling process from planning and materials procurement, to rigsite operations and results. Well Design Environmental Design Criteria The environmental design parameters for the NPI 960-L No. 1 were established by surveying then current Frio and general industry deep well experiences. Information was gathered concerning:Temperatures and pressures during drilling(refer to Figure 4) and producing modesGas production ratesGas composition (CO, H S)Produced liquids composition From the drilling and production information obtained and computer simulation of producing well conditions, the environmental design requirements were established as listed in Figure P. 317^
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