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Upon completing block fabrication, a deliberate tolerance allowance is retained on the plates to accommodate deformations induced by heat treatment during the transformation from plates to blocks. The alignment process involves aligning the reference points (master reference line) of the blocks on a common axis, facilitating the identification of excess material and deformations. This alignment process encompasses aligning the blocks with each other, employing either a three-dimensional measurement device or manual methods to obtain necessary measurements for determining excess material. In an effort to optimize time spent on block alignment and machine usage, a comprehensive methodology has been developed. This methodology involves determining excess material cuts on the blocks, performing virtual alignment operations using laser scanning techniques in a virtual environment, and conducting the cutting process on the slipway prior to placing the block excesses on it. Keywords: block excesses; scanning techniques; three-dimensional scanning technology 1. Introduction Ship construction consists of main processes including design, planning, cutting, prefabrication, block fabrication, painting, block erection, and outfitting. Workstation (WS) is a terminological concept used to define specific WS within a shipyard or a manufacturing facility. WS represents various stages of the production process, each associated with distinct tasks performed by workers. Each WS signifies a point at which multiple processes in the production line are segregated and reflects different phases of the shipbuilding process. Manuscript received at SNAME headquarters August 16, 2023; accepted December 8, 2023. Each block has its own unique manufacturing methods. The process performance evaluation of block fabrication holds a significant place in the industry (Park et al. 2014). The assembly process, determining the assembly sequence, plays a crucial role in terms of manufacturing cost, time, and quality.
- Transportation > Marine (1.00)
- Transportation > Infrastructure & Services (1.00)
- Shipbuilding (1.00)
Failure Analysis and Countermeasures for Cement Sheath Interface Sealing Integrity in Shale Gas Wells
Li, Jin (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University) | Liu, Jian (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University (Corresponding author)) | Li, Zaoyuan (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University) | Liu, Yang (CCDC Downhole Operation Company) | Yu, Caijun (CCDC Downhole Operation Company) | Song, Weitao (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University) | Wu, Xuning (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University) | Yang, Fujie (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University) | Su, Donghua (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University)
Summary Shale gas development usually uses large displacement horizontal well and staged fracturing technology to increase operation production. The complex environmental and construction conditions often lead to wellbore sealing integrity problems in the shale gas production process. This study shows a new method for evaluating the sealing integrity of shale gas cement sheath interfaces, which aims to understand the failure mechanism during shale gas production and to propose countermeasures that can effectively improve the sealing integrity of cement sheath interfaces in shale gas cementing. The study results showed that the oil contamination of cement sheath interface will greatly weaken its sealing performance. After repeated cyclic loading, the sealing performance of the conventional and expanded cement sheath assemblies is damaged, and a gas channel is formed, which is caused by the combination of microcracks and microgaps. Furthermore, oil contamination of the cement sheath interface will accelerate its sealing failure. The addition of an expansion agent is helpful to solve the problem of microgap destruction, and the fibers or whiskers can alleviate the problem of tensile cracking. The field application in the three wells proved that the toughened expanded cement slurry significantly improved the sealing integrity of the cement sheath interface in shale gas wells. The research results can evaluate and predict the sealing performance of the cement sheath interface in shale gas wells under the conditions of staged fracturing and have some directional significance for the cement slurry system optimization in the field.
Bottomhole data are acquired incrementally from sensors located in the drill string near the bit in a drilling well. Measurements may include directional information (hole inclination, azimuth, tool facing), drilling parameters (bottomhole temperature, pressure, torque, weight-on-bit, RPM), rig safety data, formation evaluation and correlation data (formation resistivity, gamma-ray, and sonic logs). Data can be transmitted to the surface in real time by pressure pulses through the mud inside the drill pipe (timed amplitude and phase encoding). Telemetry by conductor cable integrated with the drill pipe or temporary digital recording at the sensor for later wire-line retrieval are alternative data recovery methods. The term Measurement-while-drilling simply refers to the remote collection of borehole data, typically in real time, while the drill string is in place.
- Well Drilling > Drillstring Design (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Measurement, Data Acquisition and Automation > Measurement while drilling (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Application of Ultra-High Speed Rotating Shoes Offshore Indonesia - A Case History
Nkwocha, C. (Geopro Oilfield Technologies, Houston, Texas, United States of America) | Hermawan, A. (Petronas Indonesia, Jakarta, Indonesia) | Fauzan, A. Z. (Petronas Indonesia, Jakarta, Indonesia) | Ardhiansyah, F. (Petronas Indonesia, Jakarta, Indonesia) | Mahadhir, S. (Petronas Indonesia, Jakarta, Indonesia)
Abstract This paper presents two recent cases studies for high-speed rotating shoes in the East Java Sea of Indonesia where extended reach wells have been successfully drilled and completed. Rotating shoes have been used to successfully deploy 5½ inch lower completion strings in Well A, Well B, and Well C, in 2020, 2022, and 2023 respectively. Well A had the 9⅝ inch casing shoe at 15,492 feet MD with the final depth of 16,480 feet MD. Well B is currently the longest 8½ inch production lateral drilled (6,207 feet) in Indonesia at the time of this paper with a final well depth of 15,685 feet MD. The 9⅝ inch production casing shoe was set at 9,478 feet MD. Well C was eventually completed at a final depth of 14,305 feet MD with 9⅝ inch casing shoe at 10,662 feet MD. All laterals were drilled as 8½ holes and completed as 5½ inch oil producers. In Well A, a rotating shoe was used as a contingency due to its high ERD ratio in comparison to previous wells drilled in the field up until that time. In Well B string rotation was not a feasible option due to well profile and the 5½ inch completions string configuration, hence the need for rotating shoes. In Well C well bore stability issues across zones prone to loss circulation resulted in multiple sidetracks from the primary borehole, one of which was carried in the production section, thus predicating the use of a rotating reamer shoe for the 5½ lower completion. Well C was eventually completed with the third sidetrack, at a final depth of 14,305 feet MD with the 9⅝ inch production casing shoe set at 10,662 feet MD. The liner hanger was successfully set with an estimated savings over $700K for successfully deploying the lower completions Well C as estimated cost of an additional clean-out run. One reason running lower completions in these wells are successful is the use of high-speed rotating shoes. When required the rotating shoe was able to ream through obstructions while guiding the completion string into and through the drilled hole to TD. Rotating shoes are still very new to the industry and adoption is slow. However, from our experience it is evident that deployment requires appreciation of the technology and the underlying principles that make it effective, thus creating an enabling environment for proper application is paramount. This requires collaboration between end-user and supplier with good understanding of well engineering principles because the service provider will be key to a successful operation. This paper focuses on the completion operations leading to the successful deployment of the 5½ inch lower completion strings in both Wells B and C.
- Asia > Middle East > UAE > Abu Dhabi Emirate (0.30)
- Asia > Indonesia > East Java (0.25)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Bab Field > Thamama Group Formation (0.99)
- Asia > Indonesia > Java > East Java > Bojonegoro Regency > East Java Basin > Southwest Java Basin (0.99)
A Unique Methodology and Successful Implementation While Testing Exploratory Well in Bahrah Field with Several Challenges: A Case Study in North Kuwait
Alotaibi, F. Z. (Kuwait Oil Company, Ahmadi, Kuwait) | Al-Ibrahim, A. (Kuwait Oil Company, Ahmadi, Kuwait) | Ibrahim, A. (Kuwait Oil Company, Ahmadi, Kuwait) | Binsafar, A. (Kuwait Oil Company, Ahmadi, Kuwait) | Alkhulaifi, O. (Kuwait Oil Company, Ahmadi, Kuwait)
Abstract Objectives/Scope This paper presents a unique successful application and implementation of testing procedures in an exploratory cretaceous well in Bahrah field (North Kuwait). Used to evaluate productivity and characteristics of a reservoir and clearly understand the reservoir's potential, which helps in reducing the risks related to developing the field for a long-term with sustainable production, and selecting the optimum completion and artificial lift method. Methods, Procedures, Process The exploratory vertical well BH-X drilled to explore the hydrocarbon potential within the Northern Area of the Bahrah field targeting cretaceous Sandstone formation, with a total drilling depth 10,780 ft. Open-hole logs and collected WL open-hole fluid sample post drilling proved the oil bearing in the sandstone formation. The cement bond evaluation behind slim casing liner showed some doubt in quality in particularly cement image of ultrasonic tool. Decision was taken to proceed with testing without cement remediation, and perform a DST with down-hole real-time pressure gauges. The Formation interval was perforated using dynamic underbalance casing guns post displacing the completion fluid in hole OBM with filtrated brine. The Nitrogen (N2) lifting through Coiled tubing (CT) was used for well activation and to evaluate the well productivity on rig since the well ceased to flow naturally. Since these pressure events and analysis are crucial in making decisions in a low cost environment, It was decided to retrieve the downhole pressure data for preliminary Pressure Transient Analysis (PTA), which indicated that the formation skin was positive. Therefore, acid wash was performed to the sensitive sandstone formation to enhance the production rate. Results, Observations, Conclusions However, the results post the acid wash treatment showed increment in water cut. RIH with Water-Flow Log (WFL) to check the water source and identified channels behind pipe was challenging due to unavailability of E-coiled tubing. Thus, a unique solution was used to achieve a drawdown and dynamic condition while recording conventional WFL against the testing zone by using N2 and utilizing the DST tools functions. WFL results indicated the source of water behind casing above the test interval. Therefore, a cement squeeze job was performed and cement bond log was recorded again post the remedial job, which confirmed a good improvement in cement bond. The targeted interval was re-perforated utilizing dynamic underbalance perforation with STIM guns, the well was activated by CT using N2 lifting and showed clear improvement in production with zero water cut. Novel/Additive Information Overall, a unique methodology while using real time data has delivered better decision making and operational capabilities during rig and testing operations, which assists in reducing well testing operations cost and time.
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Bahrah Field > Marrat Formation (0.99)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Zubair Formation (0.98)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Zubair Field > Mishrif Formation (0.98)
Abstract Measurement-while-drilling (MWD) surveying is one of the important prerequisites for the successful delivery of directional wells because the survey defines the accurate wellbore position and orientation of the bottomhole assembly (BHA) in real time during the drilling operation. There were many modifications performed in MWD measurements evolution progress over the years, but none of them resulted in achieving the six-axis surveying measurements that obtained in dynamic conditions with at least the same accuracy as static surveys. Realizing the true potentials of taking the survey measurements in the rotating mode helped to optimize drilling operations and minimize the risks associated with stationary survey methods. The definitive dynamic survey (DDS) can be accurately performed while drilling in both rotary and slide modes. The DDS eliminated survey-related rig time, i.e., working the drillstring to release the torque, providing zero motion while making and sending downhole survey measurements, or spending additional time to resurvey the interval for various reasons. A major directional oilfield services provider pioneered a new MWD surveying technology that implemented in the projects in the Caspian Sea. The technology delivered definitive surveys while on-bottom drilling with full parameters and complete data quality control. Several operational runs have been recently conducted with the aim of comparing and qualifying DDS to industry standard gyro and MWD surveys. The MWD DDS survey was conducted in complex 3D well profiles, including a curve section and tangent at near vertical and high angle through a continuous turn interval. The results showed an excellent match both in inclination and in azimuth. Based on the results of evaluating the technology in this location, DDS surveys enhanced rig operations efficiency, improved trajectory control, and provided higher survey density than that from traditional stationary MWD surveys. This paper presents the recent results obtained from implementing the DDS technology while drilling in the Caspian Sea region and reveal the best practices for planning and performing other similar jobs. The paper includes the procedures required to take definitive non-static surveys, ensuring the DDS data are sent continuously to the surface and meet survey acceptance criteria in terms of sensor misalignments, shock and vibration parameters, eddy current compensation, and phase shift corrections. To validate these continuous survey measurements, a field test survey comparison was performed between a conventional static survey and a gyroscopic survey. In addition to a conclusion, the paper will present the recommendations for the well construction efficiency optimization while drilling through a depleted reservoir.
Flow-control accessories add to the flexibility of the cased-hole completion design and perform a multitude of tasks, such as: * Temporarily plugging off the tubing string. Profile seating nipples and sliding sleeves have a special locking groove and a honed sealbore to allow a flow-control device to lock in the nipple and seal off when installed. By design, the sleeves and nipples will have a smaller inside diameter (ID) than that of the tubing string. For this reason, careful consideration must be given to the overall application and completion design when selecting and sizing the various models of profile seating nipples and sleeves. This is especially true in any case in which through-tubing operations or perforating are planned.
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Tapered Liner System for Zonal Isolation and Hydraulic Fracturing: An Application in the Kirthar Fold Belt Region
Hussain, Muhammad Azhar (Polish Oil and Gas Company, ORLEN S.A., Islamabad, Pakistan) | Abid, Syed Asad (Polish Oil and Gas Company, ORLEN S.A., Islamabad, Pakistan) | Khalid, Muhammad Umar (Polish Oil and Gas Company, ORLEN S.A., Islamabad, Pakistan) | Sarwar, Muhammad Azeem (Polish Oil and Gas Company, ORLEN S.A., Islamabad, Pakistan) | Shahid, Sucklaj (Polish Oil and Gas Company, ORLEN S.A., Islamabad, Pakistan) | Ahmad, Hammad (Polish Oil and Gas Company, ORLEN S.A., Islamabad, Pakistan) | Gorinak, Mateusz (Polish Oil and Gas Company, ORLEN S.A., Islamabad, Pakistan) | Shaikh, Rashid Ali (Baker Hughes, Islamabad, Pakistan) | Al Lawati, Ibrahim (Baker Hughes, Islamabad, Pakistan)
Abstract This paper aims to describe the first ever successful deployment in Pakistan, of a 9-5/8″ × 7″ × 4-1/2″ Tapered Liner System with a provision of a lower PBR (rated at more than 16,000 psi) with a Vo rated Seal Stem Assembly to achieve zonal isolation and meet requisite design criteria for successful Hydraulic Fracturing of a tight reservoir zone. This insight empowers drilling Engineers to make informed decisions when selecting Liner Hanger Systems for Zonal Isolation and Hydraulic Fracturing ultimately optimizing drilling performance and wellbore stability as demonstrated in the paper. The Pab sand Formation in the Kirthar Concession Block typically exhibits permeability less than 1 mD and is categorized as "Tight". This formation is drilled and hydraulically fractured to produce at commercial flowrates. Hydraulic Fracturing at pressures in excess of 16,000 psi Bottom Hole Pressure is required to achieve necessary formation stimulation. To solve these challenges, an innovative application of incorporating a 9-5/8″ × 7″ Liner Hanger assembly with the provision of tapering 7″ Liner string to 4-1/2″ string with a Lower PBR was considered. A robust and compatible V0 rated Seal Stem Assembly stung into the lower Polished Bore Receptacle (PBR) above the 4-1/2″ liner segment would allow for DST or a Completions string to be run and completed as a monobore string. The Seal Stem Assembly would be a barrier containing the pressure loads generated due to various Production or Stimulation / Intervention cycles. The length of the seal assembly and the lower PBR were to be adjusted to allow for tube movement during these cycles. The Tapered Liner system allows for Hydraulic Set or Wireline Set Packer to be set inside the 7″ Liner segment of the Tapered assembly as a barrier, protecting the Liner Top from the high pressure loads generated during Hydraulic Fracturing – mitigating for possible leak paths. When this state of the art design was executed it has resulted in numerous deliverables to this efficient well plan. The Liner was rotated during the cement job allowing for excellent zonal isolation. The Seal Assembly was run in on a DST string and stung inside the lower PBR. The string was then pressure tested cyclically and the pressure was held successfully demonstrating robustness of the seal stem and the feasibility of the tube movement calculations. The subsequent operations included successful DST, Hydraulic Fracturing, and Well Completions operations. In conclusions, this study has substantial implications for future drilling operations in Kirthar Block wells, as reservoir sections are mostly drilled in the 8-1/2″ hole section. Given the hole stability challenges in the formations drilled above reservoir, the Tapered Liner system further allows for a 6″ hole section in the reservoir zone, casing off challenging stressed formations separately in the 8-1/2″ hole section – as demonstrated further in this paper.
- Asia > Pakistan (0.51)
- Europe > Norway > Norwegian Sea (0.25)
- Asia > Pakistan > Punjab > D.G Khan District > Pab Formation (0.99)
- Asia > Pakistan > Balochistan > Ranikot Formation (0.99)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Completion > Well Integrity > Zonal isolation (1.00)
- (4 more...)
_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 211539, “New Low-ECD Organophilic Clay-Free Inverted Emulsion Fluid Weighted With Manganese Tetroxide Showed Superior Performance in Different Fields: Success Story of Drilling With OCIEF in High-Overbalance Environment Without Downhole Problems, Stuck-Pipe Events, and Nonproductive Time,” by Vikrant Wagle, SPE, Abdullah Yami, SPE, and Abdullah Al Moajil, SPE, Saudi Aramco, et al. The paper has not been peer reviewed. _ The complete paper describes the success of using a new low-equivalent-circulating-density (ECD) organophilic clay-free inverted emulsion fluid (OCIEF) in gas reservoirs at elevated temperatures and with differential pressures up to 4,500 psi. The objective of the paper is to highlight the superior performance of OCIEF over barite-based conventional invert-emulsion drilling fluids and formate-based, water-based drilling fluids in the study. The fluid overcame challenges in such an environment without compromising performance. Introduction The new low-ECD OCIEF, using manganese tetroxide as the weighting agent, was developed with an aim to offer improved drilling performance in maturing fields. Its nondamaging nature, the result of the presence of the acid-soluble and micronized manganese tetroxide, would help to complete the well with an openhole design. In an OCIEF, the organophilic clay and organophilic lignite are replaced by a polymeric viscosifier and a polymeric filtration-control agent, respectively. A unique gel structure is provided by the use of the polymeric viscosifier in the oil-based drilling fluid. Also, it not only increases cuttings-carrying capacity but also helps to increase barite sag resistance in the fluid. In the absence of low-gravity solids in terms of organoclay and organolignite, an OCIEF shows low plastic viscosity and a higher rate of penetration compared with conventional organoclay-based oil-based muds. In the OCIEF described in the paper, the solids content has been further reduced by replacing the barite (4.2 SG) with manganese tetroxide (4.8 SG). The acid solubility of manganese tetroxide would make the drilling fluid nondamaging, especially for reservoir zones. Formulation of Low-ECD OCIEF. The OCIEF was designed for long lateral sections where low rates of penetration (ROPs) can be observed in a slimhole drilling environment with a bottomhole temperature (BHT) of approximately 300°F. The OCIEF was tested for drilling in high-static overbalance conditions (3,000–4,500 psi) and had to be resistant to potential contaminants. The OCIEF was formulated with the acid-soluble manganese tetroxide with a water-phase salinity of 200,000–250,000 ppm. Two 95-lbm/ft OCIEFs were formulated. The 95-lbm/ft OCIEF 1 was developed with an engineered bridging package of variously sized ground marbles. This formulation was specifically for short laterals and lower differential pressures. The acid solubility of the ground-marble-based package was an additional benefit of the OCIEF 1 fluid formulation. An alternate, OCIEF 2, was developed for longer intervals with higher overbalance conditions. OCIEF 2 was formulated with a bridging package that included sized resilient graphite, fibers, and sized ground marble. The bridging package was designed for longer laterals because it was expected that the bridging solids would undergo increased mechanical attrition. A single polymeric filtration-control additive was used in both formulations.
- Geology > Mineral > Sulfate > Barite (0.66)
- Geology > Rock Type > Sedimentary Rock > Organic-Rich Rock > Coal (0.55)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.55)
Discrete Element Modelling of Deep Cemented Sandstone Formation Using Adhesive Elastoplastic Contact Model
Khamitov, F. (Aalto University, Espoo) | Shabdirova, A. (Nazarbayev University, Astana) | Zhao, Y. (Nazarbayev University, Astana) | Minh, N. H. (Fulbright University Vietnam, Ho Chi Minh City)
Abstract The Thornton-Ning (TN) contact model, originally designed for self-adhesive spherical particles, was implemented into the Aspherix® commercial software, and then modified to simulate the behavior of cemented sandstone material. During the initial phase of software development, the implementation of the TN model underwent successful validation. In the subsequent phase, the TN model was adapted to replicate the characteristics of a weak cemented sandstone material. Three new assumptions were used: 1) bond breakage was defined as the point of maximum negative force, 2) bonding occurred only once during the formation of the geological material in the sample preparation, and 3) bond breakage occurred under subsequent loading conditions, any new contact was not bonded and hence modelled using the non-adhesive elastoplastic equation of the TN model. To simulate the diagenesis of sandstone material at significant reservoir depths, one-dimensional DEM compression was performed; the applied vertical stresses covered the stress range in an oil-gas reservoir. By employing an elastoplastic contact and bond model, a more realistic constitutive behavior can be achieved as compared to prior studies on the same material utilizing the purely elastic Hertz contact model.
- Asia > Kazakhstan (0.29)
- Asia > Vietnam (0.28)
- Asia > Middle East > Saudi Arabia (0.28)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)