This paper reviews the existing planning process for decommissioning projects on the United Kingdom Continental Shelf (UKCS) and explores an alternative approach of planning decommissioning activities with reference to'Facility Removal Date' rather than with reference to'Cessation of Production Date'. This alternative approach aims to enable a more effective planning of decommissioning activities in a high oil price and limited supply chain capacity environment to achieve cost reduction by: 1. Improve Supply Chain Impact on Decommissioning Projects 2. Provide Better Opportunities for Aggregation of Scope 3. Promote Development of the Supply Chain This alternative planning approach offers a way for project engineers to plan decommissioning activities by using a new point of reference which offers a clearer distinction that separates well plugging and abandonment and facility's removal operations in decommissioning projects. This alternative approach involves putting'Facility Removal Date' as the main starting point of reference when planning decommissioning activities. This is an emergent insight from research investigating development of stakeholder-oriented critical paths, which was carried out using a mixed-method methodology incorporating 1. Case Studies on Decommissioning Projects in the UKCS 2. Semi-structured Interviews with Industry Representatives in the UKCS This alternative approach demonstrates the importance of the supply chain as a stakeholder in the UKCS decommissioning landscape. This paper will discuss the anticipated increase in demand and decommissioning activities in the UKCS and how it will correspond to an increasing supply chain influence and subsequent impacts on decommissioning projects. It will also show the effect of changing well plugging and abandonment strategies over the years on the change in significance of the'Cessation of Production Date' and'Facility Removal Date'. 2 SPE-199195-MS This paper will discuss the emergent insights discovered when using'Facility Removal Date' during the development of the critical paths. It will then further discuss how using'facility removal date' in decommissioning planning can enable a more effective scheduling of activities, reduce uncertainty for the supply chain, and promote aggregation of scope, leading to cost reduction in decommissioning. The discussions will be further supported by qualitative data obtained from semi-structured interviews used for the development of the stakeholder-oriented critical paths.
Almohammad, Humoud (Kuwait Oil Company) | Ayyad, Hazim (Schlumberger) | Sultan, Alaa (Kuwait Oil Company) | Rane, Nitin (Kuwait Oil Company) | Abdulrahim, Khaled (Schlumberger) | Bumajdad, Mohammed (Kuwait Oil Company) | Mehraj, Majid (Schlumberger) | Al-Hamdan, Abdulaziz (Kuwait Oil Company) | Al-Mutairi, Norah (Kuwait Oil Company) | Al-Khamis, Abdulaziz (Kuwait Oil Company) | Al-Derbass, Abdullah (Kuwait Oil Company)
Studying the flow behavior in horizontal section addresses further challenges and complexity. Innovative technologies were developed to overcome the fluid segregation challenges in horizontal sections and cover the entire production profile. In Kuwait, horizontal production logging is typically conveyed on 1.75" electrical coiled tubing which is relatively large size and therefore increases the risk of choking the well or killing low flowrate wells. Also, there is a limitation on the availability of the electrical coiled tubing.
Greater Burgan smart ICD wells require a periodic assessment of the production profile and the contribution from each port to overcome the increasing water cut challenge in such a mature field. To identify the source of water, the engineers planned a new strategy to minimize the choking effect through use of smaller coiled tubing size. However, the available small size coiled tubing are not equipped with an electrical line for real-time data streaming. This challenge was resolved by opting for a horizontal PLT logging recording in a memory mode acquisition.
Running the production logging in memory mode is not unusual in vertical and slightly deviated wells, but it is not common in horizontal wells. Risk assessment was carried out trying to eliminate all the expected obstruction such as having a dummy run while monitoring production behavior on the surface using a testing unit, reducing the coiled tubing speed to avoid disturbing the flow stabilization and watching for any indication of coiled tubing tension-compression changes. A contingency plan was in place, for carrying out a nitrogen activation in case the well chocked below the accurate reading limits during the logging. Following the detailed steps and extensive planned procedure, the logging with memory mode in the horizontal section was successful and resulted in accurate flow profile determination along with contribution from each ICD ports. Using normal coiled tubing instead of the electrical coiled tubing has resulted in reduced operational cost and eliminate the challenge of the limited availability of electrical coiled tubing that was delaying the PLT jobs. The major production logging output was accurately presented from the memory mode.
This paper includes the challenges from using memory production logging in horizontal section. A risk assessment for each of the challenges and contingency plan to apply this method.
Over the next decade, attracting and retaining skilled workers will be one of the biggest challenges to oil and gas industry success. Talent management is a business strategy that organizations believe will enable them to retain their top talented employees and improve organization's performance. It is the process of effectively hiring the right talent, preparing them to take up top positions in future, assessing and managing their performance and also preventing them from leaving the organization. The performance of every organization depends on the performance of their employees. If the employees have unique competencies which the competitors cannot replicate, the organization automatically gains a competitive edge over its competitors. So, for managing this unique human capital, the organizations are focusing on creating effective systems and processes for talent management and the approaches to assessing current talent management efforts, identifying gaps and opportunities, and developing integrated action plans that is results-oriented and that can be aligned with each company's unique structure and long term goals. This paper highlights the positive relation between talent management and employee engagement, retention, value addition and improved organizational performance. The study reveals that there is positive association between these variables. This paper also verifies what the recent researchers thought about the positive impacts of talent management. The objectives of the study are to show the impact of Talent Management Techniques in the oil and gas industry on employee's engagement, motivation, loyalty, and performance.
The present paper has been divided into four sections. In the first part, the changes occurring in the business environment and in particular the challenges faced by the oil and gas industry have been discussed. The second section explores the concept and reviews the available literature on talent management (TM). On the basis of review of literature the factors of talent management were identified and objectives and hypotheses were formulated. In the third section research framework and research methodology finds mention. The fourth section is about results and discussions.
observations and conclusions are the harvest of different research methods used in the present study e.g. qualitative and quantitative surveys, interviews, workshops and discussion groups. Such methods are aiming at reaching verified and documented evidences of the actual findings derived from studying the impact of talent management on employees' performance and engagement.
Talent management has become a hot topic everywhere. Review of Literature will explore different definitions, approaches and point of views regarding the Talent Management concepts and techniques. The paper links between findings of literature review and actual results and observations related to current oil and gas companies
Wang, Han (College of Safety and Ocean Engineering, China University of Petroleum-Beijing) | Chen, Dong (College of Petroleum Engineering, China University of Petroleum Beijing) | Ye, Zhihui (College of Safety and Ocean Engineering, China University of Petroleum-Beijing) | Li, Jun (College of Petroleum Engineering, China University of Petroleum Beijing)
The conventional well trajectory design mainly developed from spatial mathematical model e.g. arcs or cylindrical spiral lines method, focusing on seeking optimal kickoff point and curvature. However, the complex well trajectory design requires more sophisticated and efficient method, considering greater contact with reservoir pay zone, which means time consuming computation works based on conventional well trajectory design. The automated well trajectory planning can meet such requirements, based on reservoir area identification, reservoir matrix evaluation, wellbore trajectory path generation. The present study aims to develop this algorithm for automated drilling trajectory design without assistances from human experts. Based on the stratigraphic figure of a specific reservoir, the present algorithm is able to provide an optimal trajectory with more contact zone while still meeting the curvature requirement. An intelligent planning algorithm of drilling trajectory is proposed on basis of computer vision. Based on the stratigraphic figure of a specific reservoir, the present algorithm is able to provide an optimal trajectory with more contact zone. By converting the reservoir profile (pay zone) to digital matrix and evaluating the pay zone matrix, the optimal well path is able to be automated generated. The research finding can be potential applied in geosteering drilling or autumated drilling.
Esteves Aranha, Pedro (Petrobras) | Abensur Gandelman, Roni (Petrobras) | Henrique Martins dos Santos, Pedro (Petrobras) | Borella Hougaz, Augusto (Petrobras) | Gomes Clemente, Ricardo (Intelie) | Dumlao, Vincent (Intelie) | Henrique Santos Teixeira, Pedro (Intelie) | Mazzi, Vitor (Intelie)
The act of planning a well is a collaborative effort taking disparate data from various groups and synthesizing it into one overarching program. Each operator follows its own well design process, but common to each operator is the fact that wells not designed wholly in series, but rather have many parallel sections, with a set of decision gates and countless data interdependencies. The goal of this paper is to detail the successful development and implementation of an integrated planning platform within a National Oil Company.
The individual components of well design process are not performed in a vacuum. The various inputs / outputs from one application affect the inputs/ outputs of applications both upstream and downstream of it, along the design process. This is addressed by facilitating integration and analysis of data input / output from each component of the planning process, synthesizing it, and performing automated system-integrity and overall conformity checks between the interdependent components. Any changes to an individual design component that affect other areas must be flagged, notifying the appropriate parties. Defining and automating workflows, mapping data interdependencies within the workflows, and creating a system of data governance are also keys to building an efficient planning platform. Similar to a navigation program which is able to determine an optimal driving route by considering various dynamic and static data points, the implemented platform uses a data-adaptive approach to well planning. Using this method, it takes unstructured data processes, decision trees, data integration protocols, and automates them while also permitting users to collaborate on well planning and design, allowing the standardization of processes. Operators are able to embed their particular methods of well design into the software platform and thus ensure that all of their company meet the specific requirements. Key to the effectiveness and longevity of this type of platform is a neutral data repository. Allowing data to be free of any singular data protocol ensures that although individual applications may revised, replaced, or put into competition with one another, the format of the data produced as well as ingested by these applications stays constant. Data will remain mapped, both in terms of overall process workflow and interdependencies. This paper is beneficial to any operator wishing to gain insight in developing a forward thinking of a digital strategy for well planning and design. However, the use of these types of methods and development of a similarly integrated platform an operator can standardize processes, enforce and ensure data governance, as well as gain efficiency in overall planning time.
High pressure and high temperature (HPHT) oil and gas wells have rapidly become a regular occurrence over the last decade and continue to push the boundaries of technology development where enhanced elastomers and metallurgy for completion tools are required.
This paper delivers a clear approach to streamlined deployment and value-added techniques, which were utilized to successfully install the first HPHT openhole multistage fracturing system (MSF), combined with the first HPHT monobore liner hanger completion system. A major technical challenge is the identification and qualification of 15 Kpsi openhole multistage fracturing completion equipment, which is required for the successful exploitation of tight and unconventional HPHT reservoirs. The integration of two technologies from two service companies, qualified to overcome this requirement, called for unprecedented well planning; from engineering design assessment, systems integration appraisal, risk assessment with contingency planning to repeated modeling (geomechanic, drilling fluid, etc.), completion well on paper exercises, with planning improvements in well design and drilling equipment to achieve this breakthrough.
As with any technology, operational design, planning, and execution play key roles on many levels in ensuring successful deployment. This can only be achieved through stakeholder acceptance of relevant advanced technologies, globally accepted best practices, collaboration of industry experts and precise planning. This should be the case with any project deployed in the oil and gas industry, especially when technical specifications require working capabilities of 15 Kpsi and 375°F. With this breakthrough, the integrated 15 Kpsi multistage frac and monobore liner hanger completion technology was a suited application for a tight gas field.
Tangen, Geir Ivan (Lundin Norway AS) | Smaaskjaer, Geir (Lundin Norway AS) | Bergseth, Einar (Lundin Norway AS) | Clark, Andy (Lundin Norway AS) | Fossli, Børre (Enhanced Drilling AS) | Claudey, Eric (Enhanced Drilling AS) | Qiang, Zhizhuang (Enhanced Drilling AS)
In 2015, while coring in the carbonate reservoir in the second appraisal well on an oil and gas discovery in the Barents Sea (386 m water depth), the drill string fell 2 meters and a total mud loss was experienced leading to a well control incident. As a result, since 2016, the operator has introduced and used the Controlled Mud Level (CML) system. To date this system has been used on seven wells including two further appraisal wells on the same field and five exploration wells in the area.
In 2017 it was decided to drill a horizontal well in the same carbonate reservoir and to perform an extended production test in close proximity to the original loss well. Since it is not possible to predict where large voids (karsts) and natural fractures could be encountered, contingency to handle high losses, had to be implemented for the horizontal well. During the well planning, further risk reducing measures were implemented, including the use of wired drill pipe to improve the management of the wellbore pressure profile. This paper describes the planning processes leading up to the operation and the highlights of the operation itself together with the lessons learned. It elaborates on how wired pipe, used in combination with the CML system, added value to the operation. It shows how it was possible to drill the reservoir section with a low overbalance while managing severe losses associated with open karsts and natural fractures and still maintaining the fluid barrier. Despite the severe losses encountered it was possible to safely drill and complete the well without any well control event by use of the CML system.
Essam, Wael (BP) | Scarborough, Christopher (BP) | Wilson, Nick (BP) | Shimi, Ahmed (BP) | Santos, Helio (Safekick) | Hannam, Jason (Safekick) | Catak, Erdem (Safekick) | Lancaster, Jay (Seadrill) | Gooding, Neil (Seadrill) | Baan, Robert (Seadrill)
BP had long recognized the benefits of MPD, having been using it for years to deliver very challenging wells in Egypt, Trinidad and the North Sea; and it was time to bring these benefits to its GoM operations. Once the company team identified a portfolio of suitable candidate wells to allow the economics of the application to be advantageous, they partnered with Seadrill to provide the MPD service integrated into the West Capricorn drilling rig. This approach builds on synergies within the drilling contractor organization to achieve long term economic, competency, and risk management benefits, resulting from integrating this drilling method on the rig, and eliminating interfaces with 3rd party providers. The paper will discuss how the company and the drilling contractor teams, together with equipment suppliers and training providers, managed the project from initial system design, to installation and commissioning, to the successful delivery of the first well using MPD, at top quartile performance. It will discuss the process for optimizing the design and testing it from a reliability and process safety perspectives; engaging the regulatory authority and the classification society; integrating MPD in the well planning process and developing operational procedures for use on the rig; and delivering a training program for the wider team covering the technical and the human factors aspects to ensure a successful delivery.
With a shallow water flow-back in excess of 200 bbl/hr from the Top Chalk formation during the 17½" section, the deviated exploration / development well "Well #4" was planned and drilled successfully with a jackup rig. The well was planned from a platform in the Southern North Sea.
The primary goal for the 17½" section was to safely drill to section TD, set casing and cement same with zero incident in a minimum amount of time while encountering shallow water flow.
The key challenges for this well were: Flowing Top Chalk Formation: The Top chalk formation flowed at all three previously drilled offset wells with 12.0 ppg EMW and approximately 200 bbl/hr. Several attempts to shut in the well and stop the flowing Top Chalk on the offset well "Well #1" failed. Obtaining regulatory approval from authorities, and commitment and acceptance by all involved parties to drill the well under flowing conditions. Hole cleaning and hole stability considerations when drilling with seawater Permanently shutting off the shallow water flow with a two-stage cementation. Rig uncertainty and general service market (in 2017): A new drilling contractor and drilling services not familiar with the peculiarities of operations in this area Safety, communication and human factor considerations for a potentially hazardous non-routine operation.
Flowing Top Chalk Formation: The Top chalk formation flowed at all three previously drilled offset wells with 12.0 ppg EMW and approximately 200 bbl/hr. Several attempts to shut in the well and stop the flowing Top Chalk on the offset well "Well #1" failed.
Obtaining regulatory approval from authorities, and commitment and acceptance by all involved parties to drill the well under flowing conditions.
Hole cleaning and hole stability considerations when drilling with seawater
Permanently shutting off the shallow water flow with a two-stage cementation.
Rig uncertainty and general service market (in 2017): A new drilling contractor and drilling services not familiar with the peculiarities of operations in this area
Safety, communication and human factor considerations for a potentially hazardous non-routine operation.
A collaborative well-planning and preparation process involving the operator drilling team, the drilling contractor and key service providers was critical to the success of the overall operation.
The team worked together to ensure all requirements, risk mitigating measures, lessons learned from previous operations and offset wells, and human factor considerations were incorporated in the execution program.
The well was successfully drilled to TD, evaluated, completed and flowed. The notable highlights from the top-hole drilling operation include: Fastest 17-1/2" phase compared to offset wells: drilling and casing operations completed in 94.25 hrs with the well flowing. Zero NPT in the 17-1/2" drilling phase: drilled 654 m in 37.5 hrs with an average ROP of 17.5 m/hr without any complications. Continuous monitoring and fingerprinting of the shallow water flow
Fastest 17-1/2" phase compared to offset wells: drilling and casing operations completed in 94.25 hrs with the well flowing.
Zero NPT in the 17-1/2" drilling phase: drilled 654 m in 37.5 hrs with an average ROP of 17.5 m/hr without any complications.
Continuous monitoring and fingerprinting of the shallow water flow
This paper describes the key planning considerations, preparations and creative solutions deployed to deliver the well. The lessons learnt will serve as a resource for planning future wells with similar challenges.
This paper identifies several best practices for improving employee competency and productivity. They include aligning reward and promotion practices with company core values, promoting those who are already leading and have the capacity to perform at the next level, and using both internal and external benchmarking to help employees to set stretch goals for competency training and improving productivity.