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Complete MPD Rig: Time for Jack-Ups Now
Gedge, Benjamin (PVD Well Services Co Ltd) | Binh, Cao (PVD Well Services Co Ltd) | Vuong, Trinh (PVD Well Services Co Ltd) | Hai, Nguyen (PVD Well Services Co Ltd) | Yaw, Norman (Regional Marine & Engineering Pte Ltd) | Mardon, Jeff (Regional Marine & Engineering Pte Ltd) | Frohlich, Herbert (Regional Marine & Engineering Pte Ltd) | Gooding, Neil (Seadrill) | Santos, Helio (Safekick)
Abstract Four years ago (IADC/SPE-191099) the move was clear on floating rigs​; to have them fully equipped with a Complete MPD package, the economic justification was very strong. Currently, there are around 20 floating rigs with a Complete MPD package, permanently installed. For Jack-Ups, however, the same move started only recently, with a few rigs now equipped with a Complete MPD package, using the same philosophy applied to a floating rig. The paper initially describes the success obtained by the Complete MPD​ floating rigs, not only from an economic, but also from a technical point of view, with operations in Australia, Brazil and the Gulf of Mexico. Having the MPD package permanently installed and ready to use, operators are now deploying MPD for the total well construction process, with a rig crew competent in running the MPD system, from spud to the T.D. of the well. This includes running casing/liner, cementing and, also, completions. The paper outlines the benefits and advantages for both the operators and drilling contractors, showing they are significant. Companies are taking advantage of having the MPD system on the rig and being able to maximise the full benefits. With all the success seen on floating rigs​, operators start​ed to realize the benefits of using the same approach for Jack-Ups, building on previous experience with temporary MPD installations on Jack-Ups, ​learning from what worked and what did not work. The paper de​scribes the recent Complete MPD Jack-Up installation in Norway ​(implemented under the new MPD NORSOK requirements, which made it even more challenging​), the success achieved with the first wells drilled, and how the economics will work for the Jack-Up market, in the same way it works for the floater market. The technical benefits are the same, as the system used on the Jack-Up is equivalent and has the same features of the systems used on the floating rigs. The paper finally addresses the Asia Pacific market, which is dominated by Jack-Up rigs over floaters. The economic, technical, HSE and logistical benefits make it an appealing proposition to have a Complete MPD Jack-Up rig, and they are all discussed in detail. An example is used with a Jack-Up operating in the region, clearly demonstrating its similarity to a floating rig when adopting the same Complete MPD Rig approach.
- Asia (0.67)
- South America > Brazil (0.24)
- Oceania > Australia (0.24)
- (3 more...)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- Well Drilling > Drilling Operations (1.00)
Complete MPD Rigs: Is This the Future?
Gedge, Ben (Regional Marine & Engineering – PVD Well Service Co Ltd) | Yaw, Norman (Regional Marine & Engineering) | Postel, David (Regional Marine & Engineering) | Mardon, Jeff (Regional Marine & Engineering) | Frohlich, Herbert (Regional Marine & Engineering) | Nguyen, Bot Viet (PVD Well Service Co Ltd) | Thanh, Ban Nguyen (PVD Well Service Co Ltd) | Hong, Duc Vu (PVD Well Service Co Ltd) | Barbee, Brian (Ensco) | Santos, Helio (Safekick) | Gouldin, David (Seadrill)
Abstract There has been a lot of discussion around rigs with some capability to perform Managed Pressure Drilling - MPD - operations, with rigs having different permanent equipment installed. But all the rigs, somehow, would all be classified as ready to perform MPD operations. In order to clarify a bit this subject, this paper clearlt differentiates rigs with some permanent equipment installed, but the specialized MPD equipment and service are still provided by a service company, which is herein called MPD-Capable-Rigs, from rigs which have installed all the equipment needed for MPD, and the drilling contractor is the one offering the service, which is called Complete-MPD-Rigs. The objective of the paper is to discuss and illustrate what is involved in preparing an offshore and even onshore Complete-MPD-Rig. The paper also discusses the evolution of MPD, initially provided by service companies, with equipment needed to be rigged up and down on rigs, all the way to current stage where drilling contractors are providing the service directly. To achieve this stage the drilling contractors are equipping their rigs with the full MPD package and providing the service directly to the operators. The paper describes the evolution of equipment installed and owned by the rig, from a few lines in the very beginning to a complete packge today. The movement towards the drilling contractor owning and offering the MPD service started with the deepwater rigs, but evolved to onshore rigs also. Today, both onshore and offshore drilling contractors Complete-MPD-Rigs. Some examples of rigs with partial equipment installed are provided, illustrating the evolution of what a rig would own, until the most recent onshore and offshore examples of Complete- MPD-Rigs. This is definetly the future as it simplifies not only contractual and legal aspects but also improves a lot the competency of the rig crew and significantly reduces the problems of communications during an MPD operation when the equipment is not owned and provided by the rig.
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- Well Drilling > Drilling Operations (1.00)
Intelligent Completions First Implementation of Injector Multi-Zones – Injectivity Optimization and Efficiency for IOR Integrated Operation
Razak, M. Firdaus (PETRONAS) | Khalid, Aizuddin (PETRONAS) | Sapian, Nik Fazril (PETRONAS) | Madzidah, Asba (PETRONAS) | Samuel, Orient Balbir (PETRONAS) | Khalid, M. Zaidan (PETRONAS) | Mohd, Shamsulbahri B. (PETRONAS) | Bakar, M. Farris (PETRONAS) | Salih, Mohamed Sharief (PETRONAS) | Ruvalcaba, Jazael Ballina (PETRONAS) | Sadan, Nur Syazana (PETRONAS) | Misron, M. Al-Perdaus (PETRONAS) | Afzan, A. Satar (PETRONAS) | Jamal, Ajmal Faliq (PETRONAS) | A'akif, Nurul Aula (PETRONAS) | Mohr, Ludovic (PETRONAS) | Tajuddin, Nor Baizurah (PETRONAS) | Kalidas, Sanggeetha (SCHLUMBERGER) | Faizah, P. Mosar (SCHLUMBERGER) | Goh, Gordon (SCHLUMBERGER) | Tan, Tina (SCHLUMBERGER) | Palanisamy, Ravishankar (SCHLUMBERGER) | Luke, Darren (SCHLUMBERGER)
Abstract The ‘B’ Field is located about 40 KM, offshore Sarawak and was discovered in 1967 with 70-80 m water depth. Structurally, ‘B’ field is charaterised by a simple relatively flat, low-relief domal anticline which is bounded to the north and south by the north-hading growth faults. The major faults are acted as effective lateral seal, which is indicated by the difference in the fluid type and fluid contacts across those faults. ‘B’ field consist of multiple hetereogenous sandstone reservoirs with permeability and porosity ranging from 25 −1700 mD and 16 −29% respectively. ‘B’ Field injectivity conformance for reservoir pressure support is very crucial as the field is undergoing severe depletions over years and unable to meet the production target. The Operator realized the importance in order to further increase the recovery factor, hence has included ‘B’ field in the Improved Oil Recovery (IOR) project to boost the production and prolong ‘B'field's life. Based on comprehensive IOR/EOR screening study, water injection process has been identified as the most amenable IOR process in ‘B'field. Hence, in Phase 1 drilling campaign, two (2) water injectors were drilled in 2016 in order to achieve the target oil recovery. Both well BWI-01 and BWI-02 were completed with Intelligent completions (IC) and expected to come online in Q4 2018. This paper further discusses the injection strategy in ‘B’ field multi-zones to meet the zonal injectivity and reservoir zonal voidage replacement requirement for pressure maintenance over field production life. The discussion covers the reservoir characteristics and zonal injectivity challenges with surface constraints that require intelligent completions solution for IOR phase. Completions architecture and customized metallurgy needs is crucial to meet operational challenges. Fit-for-purpose and maintaning development cost is pre-requisite to achieve well injection performance for optimal production
- Geology > Structural Geology (0.54)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.54)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.70)
Case History of the First TAML Level 5 Junction on a Rod-Pump Well
Ma, Qingming (Shengli Drilling Technology Research Institute (Sinopec)) | Zhonghua, Wu (Shengli Drilling Technology Research Institute (Sinopec)) | Rayne, Lance (Schlumberger) | Fould, Jeremie (Schlumberger) | O’Rourke, Tim (Schlumberger) | Hai Long, Wang (Schlumberger) | Lee, Junn Shyong (Schlumberger) | Ritchie, William (Schlumberger)
Abstract The oil industry uses multilaterals for many reasons; lower cost, smaller footprint, environmental issues, and an increase in reservoir contact to an increase reservoir production. This paper presents a case study of a TAML Level 5 multilateral junction installed in one of China's largest oil fields. What is unique about this installation is the mechanism and completion used to lift the oil to surface. This is the first time a TAML Level 5 junction and a pumpjack have been paired for lifting production. In the past, it was believed that multilateral junctions in this type of environment were not cost effective. The paper will discuss the TAML definitions, and in particular, the well conditions that led to the selection of the Level 5 junction. Installing a multilateral junction involves multiple processes that are addressed in the planning and implementation process, including reservoir selection, drilling, and completion of the well. These processes also led to the selection of the proper multilateral system to achieve the objectives for the well. This paper also covers some of the planned decisions that needed to be altered due to unpredicted well conditions. The successful installation and completion obtained from this well show that a Level 5 junction can be a successful option for a more diverse range of applications than previously thought; even on a well that uses a traditional rod pump for production.
- Asia > China > Shandong > North China Basin > Shengli Field (0.99)
- Asia > China > Bohai Basin (0.99)
Design and Application of 735hp 4000m Plateau Mountain Rig
Yan, Zengxuan (Qinghai Drilling Company of CNPC Xibu Drilling Engineering Company Limited Company) | Xu, Hongwei (Qinghai Drilling Company of CNPC Xibu Drilling Engineering Company Limited Company) | Liu, Guanghui (Qinghai Drilling Company of CNPC Xibu Drilling Engineering Company Limited Company) | Li, Qinghong (Qinghai Drilling Company of CNPC Xibu Drilling Engineering Company Limited Company) | Wang, Jianhong (Qinghai Drilling Company of CNPC Xibu Drilling Engineering Company Limited Company) | Ma, Xianping (Qinghai Drilling Company of CNPC Xibu Drilling Engineering Company Limited Company) | Zhao, Feng (Qinghai Drilling Company of CNPC Xibu Drilling Engineering Company Limited Company) | Li, Qingyu (Qinghai Drilling Company of CNPC Xibu Drilling Engineering Company Limited Company) | Yang, Shiquan (Qinghai Drilling Company of CNPC Xibu Drilling Engineering Company Limited Company) | Sun, Lin (Qinghai Drilling Company of CNPC Xibu Drilling Engineering Company Limited Company)
Copyright 2012, IADC/SPE Asia Pacific Drilling Technology Conference and Exhibition This paper was prepared for presentation at the IADC/SPE Asia Pacific Drilling Technology Conference and Exhibition held in Tianjin, China, 9-11 July 2012. This paper was selected for presentation by an IADC/SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the International Association of Drilling Contractors or the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the International Association of Drilling Contractors or the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the International Association of Drilling Contractors or the Society of Petroleum Engineers is prohibited.
- Well Drilling > Drilling Equipment (1.00)
- Well Drilling > Drilling Operations (0.95)
Embracing the Challenges - Installation of the Deepest Level 4 Multilateral Cemented Junction
Hua, An Wen (Tarim Oilfield Company) | Qing, Teng Xue (Tarim Oilfield Company) | Tong, Yang Xiang (Tarim Oilfield Company) | Xiang, Bai Deng (Tarim Oilfield Company) | Ponton, Calvin (Halliburton) | Durst, Doug (Halliburton)
Abstract To increase and optimize single well production performance, multilateral drilling and completion technology were implemented from a new single wellbore deep in the Tarim Desert of the Xinjiang Province in northwestern China. Although planning and preparation began in earnest in Tianjin months in advance of the actual installation, the on-site demands, distant logistics support, and the well depth operational demands of the project installation were the most challenging steps in the process. The remote location of the multilateral well in the Tarim Desert proved to be an operational and logistical challenge in terms of time (4- to 5-days travel time by vehicle) and distance (3600 kilometers) to the nearest repair and maintenance facilities in Tanggu, Tianjin Province in eastern China. The well design was based on a vertical pilot well, or motherbore, drilled and cased into the reservoir. The multilateral system was then installed to add another wellbore, thereby increasing reservoir exposure. The goals of this system were to accelerate production, increase ultimate recovery and, for this particular operator, qualify multilateral technology for application in this specific field. Because of the unprecedented depth of the proposed junction, thorough project management and planning were required throughout, from the feasibility phase through the execution phase, to mitigate risk and to promote a successful project installation. Strong collaboration between the operator and service supplier resulted in the world's deepest TAML Level 4 cemented multilateral installation at 5082 m TVD junction depth and 5889 m MD at the lateral toe. This was also the first multilateral installation by Tarim Oil Company and the first cemented Level 4 multilateral installation in China. This paper describes the objectives, challenges, best practices, contingencies, logistics issues, results, and lessons learned from the implementation of this deep-set multilateral technology.
Abstract Intelligent completions were introduced over a decade ago to address completions and reservoir management challenges arising from highly-deviated, extended-reach, multi-targeted, or multilateral wells. Recent advances in exploration and drilling technology are enabling the oil and gas industry to target reservoirs with stratigraphic and depositional complexities in deepwater, subsalt, arctic, and other extreme environments, resulting in the need to develop a new generation of intelligent completion tools. These reservoirs also may be characterized by HPHT, extreme HPHT, or ultra-HPHT environments with multiple components contributing to the uncertainty of recovery. This paper describes how the requirements of current and future reservoir environments and a decade of operational experience have shaped the functional design and qualification of a new-generation Interval Control Valve (ICV) for intelligent completions. The new-generation ICV has higher pressure and temperature tolerances to cater to the new harsher environments while simplifying its operating mechanism and improving inflow performance and debris tolerance. The qualification program included metal-to-metal seal qualification, life-cycle testing, API 14A SCSSV class II- sand slurry based tests, flow coefficient (Cv) test, seal stack qualification, and erosion testing. Descriptions of each qualification test, acceptance criteria and test results that demonstrate the capability of the new generation of ICV to perform in severe service conditions are presented in this paper. Field applications of the second generation valve have shown additional operational benefits not even considered during the design. Technologies such as real time ICV position feedback have further aided in maximizing efficiency by enabling the use of downhole or surface positioning. Surface positioning devices can choke flow by varying ICV positions. The use of surface positioning enhances reliability by reducing the number of tools required downhole. Finally the paper outlines the operational limits of the current design and discusses the design enhancements planned for the next generation ICV.
- North America > United States > Gulf of Mexico > Gulf Coast Basin > Wilcox Trend Formation (0.99)
- Europe > Italy > Adriatic Sea > Adriatic Basin > Aquila Field (0.98)
An Integrated System for Improving Geotechnical Performances of Jackup Rig Installation
Quah, M.. (Keppel Offshore & Marine Singapore) | Cahyadi, J.. (Keppel Offshore & Marine Singapore) | Purwana, O. A. (Keppel Offshore & Marine Singapore) | Krisdani, H.. (Keppel Offshore & Marine Singapore) | Randolph, M. F. (Centre for Offshore Foundation Systems, The University of Western Australia)
Abstract Predictability and consequential safety of jackup rigs during installation and removal remain non-trivial issues for the industry despite larger deployment of jackup rigs and operations in emerging frontier regions with more complex soil conditions. Jackup foundation hazards such as unpredicted leg penetration, rapid leg penetration, punch-through, spudcan-footprint interaction and leg extraction difficulties continue to occur in spite of the industry stepping up efforts to better control of the risks. Apart from improvements of the installation guideline and practice within the industry as well as implementation of proper site specific assessments, safer performance of jackup rigs may be achieved through advancement in jackup instrumentation technology. In the present paper, a new instrumentation technology integrated with jackup rigs is proposed to assist the jackup operators in making decision and taking measures to prevent or mitigate potential geotechnical hazards, particularly punch-through.
Copyright 2010, IADC/SPE Asia Pacific Drilling Technology Conference and Exhibition This paper was prepared for presentation at the IADC/SPE Asia Pacific Drilling Technology Conference and Exhibition held in Ho Chi Minh City, Vietnam, 1-3 November 2010. This paper was selected for presentation by an IADC/SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the International Association of Drilling Contractors or the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the International Association of Drilling Contractors or the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the International Association of Drilling Contractors or the Society of Petroleum Engineers is prohibited.
- Well Completion > Completion Monitoring Systems/Intelligent Wells > Downhole sensors & control equipment (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- (4 more...)
Abstract The Handil field is a giant mature oil field in Indonesia. It has been producing since 1975 with current recovery factor for oil is 49% and gas is 57%. Cumulatively, oil had been produced around 855 MMstb and gas around 1.68 Tcf. Now, from this field, oil is being produced at 20,000 bopd, gas at 75 mmscfd and water at 130,000 bwpd. One of the feasible and economic ways to recover the remaining oil at this late stage of field production is by doing a Light Workover technique. This technique aims to change the well status without pulling out the existing completion. This technique is considered the optimum way to maintain the field production performance up to now. One of Light Workover technique is to do re-completion by inserting smaller completion inside existing completion. An innovative spool adapter was utilized to be able to run smaller completion and sit above existing wellhead. Hence, from three (3) depleted gas wells that were converted into oil wells, all wells are still producing and economically had been paid out the intervention cost. This technique is considered applicable for a mature oil field where some gas wells had been depleted and oil layers are exist.