New Well Intervention Means as an Answer to Offshore Minimalist Platform Concept: A Breakthrough from Mahakam, Indonesia

2021 ◽  
Author(s):  
Risal Rahman ◽  
Reyhan Hidayat ◽  
Pratika Siamsyah Kurniawati ◽  
Rantoe Marindha ◽  
Gerardus Putra Pancawisna ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Cost Optimization ◽  
Oil And Gas Industry ◽  
Project Planning ◽  
Gas Industry ◽  
Safety Issues ◽  
Coiled Tubing ◽  
Remote Operation ◽  
Innovation And Technology ◽  
Hazardous Zone

Abstract Nowadays oil and gas industry are encouraging the independents and majors to take a fresh look at the technology and concepts required to develop marginal shallow water fields using a minimal platform approach. Innovation on well intervention means (lighter, smaller and less footprint) that fit for Offshore Minimalist Platform (OMP) is needed, including optimizing time and cost during well intervention activities in OMP. To achieve the objectives, well intervention innovation and technology are the main focuses. Intervention activities commonly done on campaign basis with several units (slickline, wireline, coiled tubing, testing) shall be integrated in a safe manner. The approach of integration shall signify these points:Identifying potential jobs in OMP to be done by well intervention methodsIdentifying necessary well intervention means and methods to support the jobs (combo unit, micro coil, hazardous zone redefinition, remote operation)Creating project planning and schedulingPerforming site visit and risk assessmentImplementation and operational executionEvaluation of overall project execution result The following results were obtained after the integration performed:No major safety issues during operationExemplary method and risk assessment for well intervention activities which can be applied for next campaignsTrials on well intervention new units and method (combo unit, micro coil, hazardous zone redefinition, remote operation), were safely performed with some optimization100% success ratio60% on supply boat arrangement35% efficiency in N2 consumption for CT operation45% efficiency in diesel consumption20% - 40% efficiency in Rig Up Time28% less in Job Cost compared to conventional unit These innovations are proven as reliable method to answer OMP challenges with main advantages on footprint and cost optimization. Through this paper, we would like to share lucrative well intervention breakthrough and innovation in OMP with measurable milestones.

Mutual Development

2010 ◽  
Vol 22 (2) ◽  
pp. 36-57 ◽  
Author(s):  
Anders I. Mørch ◽  
Renate Andersen
Keyword(s):  
Oil And Gas ◽  
System Development ◽  
Research Question ◽  
Oil And Gas Industry ◽  
Project Planning ◽  
Gas Industry ◽  
Main Research ◽  
Software Product ◽  
Software House

The article presents and analyzes data from a case study in customer-initiated software product development. We have observed and participated in system development activities in a commercial software house (company) over a period of two years. The company produces project-planning tools for the oil and gas industry, and relies on interaction with customers for further development of its products. Our main research question is how customers and professional developers engage in mutual development mediated by shared software tools (products and support systems). We have used interviews with developers and customers as our main source of data, and identified the activities (from use to development) where customers have contributed to development. We analyze our findings in terms of co-configuration, meta-design and modding to name and compare the various stages of development (adaptation, generalization, improvement request, specialization, and tailoring).

Analysis of Applicability of Approaches to Factor Analysis During the Monitoring Investment Projects Cost Deviations in Oil and Gas Industry

2017 ◽  
Vol 6 (3) ◽  
pp. 3-18
Author(s):  
Игорь Демкин ◽  
Igor Demkin ◽  
Д. Власов ◽  
D. Vlasov ◽  
Владимир Бархатов ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Project Planning ◽  
Planning System ◽  
Project Portfolio ◽  
Gas Industry ◽  
Investment Projects ◽  
Limited Opportunity ◽  
Proactive Measures ◽  
Oil And Gas Companies

Strategic projects of oil and gas companies regularly overcome the budget. High capitalization of these projects leads to the fact that even small relative cost deviations result in significant additional investments. Under present conditions of economic and political pressure, characterized by a limited opportunity to raise loan capital, there can be no additional investments leading to impossibility of new oil and gas projects realization or stop those being realized. One of the ways to prevent such a negative scenario is to improve the project planning system taking into account the results of monitoring the project portfolio cost deviations. It will not only allow companies to take into account the causes of deviations in several projects, but also help to develop and implement proactive measures.

Evolution of Completion Techniques in the Lower Shaunavon Tight Oil Play in Southwestern Saskatchewan

2015 ◽  
Author(s):  
D. J. Schlosser ◽  
M.. Johe ◽  
T.. Humphreys ◽  
C.. Lundberg ◽  
J. L. McNichol
Keyword(s):  
Oil And Gas ◽  
New Technology ◽  
Oil And Gas Industry ◽  
Field Trials ◽  
Gas Industry ◽  
Point Energy ◽  
Horizontal Drilling ◽  
Oil Reserves ◽  
Coiled Tubing ◽  
Open Hole

Abstract The Oil and Gas industry has explored and developed the Lower Shaunavon formation through vertical drilling and completion technology. In 2006, previously uneconomic oil reserves in the Lower Shaunavon were unlocked through horizontal drilling and completions technologies. This success is similar to the developments seen in many other formations within the Williston Basin and Western Canadian Sedimentary Basin including Crescent Point Energy's Viewfield Bakken play in southeast Saskatchewan. In the Lower Shaunavon play, the horizontal multistage completion era began in 2006, with horizontal divisions of four to six completion stages per well that utilized ball-drop sleeves and open-hole packers. By 2010, the stage count capabilities of ball-drop systems had increased and liners with nine to 16 stages per well were being run. With an acquisition in 2009, Crescent Point Energy began operating in the Lower Shaunavon area. The acquisition was part of the company's strategy to acquire large oil-in-place resource plays. Recognizing the importance that technology brings to these plays, Crescent Point Energy has continuously developed and implemented new technology. In 2009, realizing the success of coiled tubing fractured cemented liners in the southeast Saskatchewan Viewfield Bakken play, Crescent Point Energy trialed their first cemented liners in the Lower Shaunavon formation. At the same time, technology progressed with advancements in completion strategies that were focused on fracture fluids, fracture stages, tool development, pump rates, hydraulic horsepower, environmental impact, water management, and production. In 2013, another step change in technology saw the implementation of coiled tubing activated fracture sleeves in cemented liner completions. Based on field trials and well results in Q4 2013, Crescent Point Energy committed to a full cemented liner program in the Lower Shaunavon. This paper presents the evolution of Crescent Point Energy's Lower Shaunavon resource play of southwest Saskatchewan. The benefits of current completion techniques are: reductions in water use, increased production, competitive well costs, and retained wellbore functionality for potential re-fracture and waterflooding programs.

Cost Element Modelling, Prediction and Optimization in a Dual-Completion Well During a Coiled Tubing Unloading Operation

2021 ◽  
Author(s):  
Merit P. Ekeregbe
Keyword(s):  
Mathematical Model ◽  
Decision Making ◽  
Cost Estimation ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Correct Prediction ◽  
Reservoir Pressure ◽  
Gas Industry ◽  
Coiled Tubing ◽  
The Mathematical Model

Abstract In an era where cost is a significant component of decision making, every possibility of reducing operational cost in the Oil and Gas industry is a welcome development. The volatile nature of the Oil market creates uncertainty in the industry. One way to manage this uncertainty is by the ability to predict and optimize our operations to reduce all of our cost elements. When cost is planned and predicted as accurately as possible, the operation optimizations can be managed efficiently. Practically, all new drills require CT unloading of the completion or kill fluids to allow the natural flow of the wells. Hitherto, there is no mathematical model that combines information from one of the wells in an unloading dual completion project that can be used to aid decision-making in the other well for the same unloading project and thereby result in an effective cost-saving. Deploying the mathematical model of cost element prediction and optimization can minimize operational unloading costs. The two strings of the dual completion flow from different reservoirs. Still, the link between the two drainages post completion is the kill fluid density, and can aid in cost estimation for optimum benefit. The lesson learned or data acquired from the lifting of the slave reservoir string can be optimized to effectively and efficiently lift the master reservoir string. The decision of first unloading the slave reservoir string is critical for correct prediction and optimization of the ultimate cost. The mathematical model was able to predict the consumable cost elements such as the gallon of nitrogen and time that may be spent on the long string from the correlative analysis of the short string. The more energy is required for unloading the short string and it is the more critical well than the long string because it is the slave string since no consideration as such is given to it when beneficiating the kill fluid to target the long string reservoir pressure with a certain safety overbalance. The rule for the mud weight or the weight of the kill fluid is the highest depth with highest reservoir pressure which is the sand on the long string. With the data from the short string and upper sand reservoir, the lift depth and unloading operation can be optimized to save cost. The short string will incur the higher cost and as such should be lifted last and the optimization can be done with the factor of the LS.

Mutual Development

2012 ◽  
pp. 103-125 ◽  
Author(s):  
Anders I. Mørch ◽  
Renate Andersen
Keyword(s):  
Oil And Gas ◽  
System Development ◽  
Research Question ◽  
Oil And Gas Industry ◽  
Project Planning ◽  
Gas Industry ◽  
Main Research ◽  
Software House ◽  
Further Development

The article presents and analyzes data from a case study in customer-initiated software product development. We have observed and participated in system development activities in a commercial software house (company) over a period of two years. The company produces project-planning tools for the oil and gas industry, and relies on interaction with customers for further development of its products. Our main research question is how customers and professional developers engage in mutual development mediated by shared software tools (products and support systems). We have used interviews with developers and customers as our main source of data, and identified the activities (from use to development) where customers have contributed to development. We analyze our findings in terms of co-configuration, meta-design and modding to name and compare the various stages of development (adaptation, generalization, improvement request, specialization, and tailoring).

Buzios: The Biggest Ultra-Deepwater Oilfield to Date

2021 ◽  
Author(s):  
Jose Olavo de Andrada Ignacio de Oliveira ◽  
Pedro Lemos Tavares ◽  
Victor Costa da Silva ◽  
Ivan Noville Rocha Correa Lima ◽  
João Francisco Fleck Heck Britto ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Production Systems ◽  
Oil And Gas Industry ◽  
Project Planning ◽  
Development Plan ◽  
Data Sampling ◽  
Well Test ◽  
Gas Industry ◽  
Field Development ◽  
Seismic Acquisition

Abstract The purpose of this paper is to present a general overview of the Buzios field development plan, projects’ features, and main achievements so far. The development plan adopted a strategy to pursue the balance between acceleration and cash flow optimization, to maximize the return on the huge investment on the block acquisition, and the risk management related to developing several Greenfield Projects simultaneously. To reduce reservoir uncertainties, a comprehensive data acquisition plan was crafted and implemented considering: (a) seismic acquisition, (b) drilling, logging and testing several exploratory and appraisal wells, (c) massive rock and fluid data sampling along the reservoirs, (d) execution of one Extended Well Test and three Early Production Systems. Additionally, the basic design of wells, subsea systems and Floating Production Storage and Offloading ("FPSO") provided flexibility to cover remaining uncertainties yet present in the Transfer of Rights ("ToR") scope, which allows up to 3,150 billion barrels of oil equivalent ("boe") to be produced. This led to technological challenges that needed to be addressed during project planning. We believe that the innovative solutions applied enhanced currently available technologies and delivered an important legacy to the offshore oil and gas industry. Finally, the results obtained so far, with the ramp-up of Buzios projects 1, 2, 3, and 4 provide evidence of the successful adopted strategy and reinforce the decision of deployment of a fifth FPSO under the scope of the ToR contract. The strong results of the asset led to the acquisition of 90% of the Transfer of Rights Surplus ("ToR+"), together with CNOOC Petroleum Brasil Ltda. (5%) and CNODC Brasil Petróleo e Gás Ltda. (5%), which now paves the way for a second wave of development, including the deployment of up to seven additional FPSOs.

Data Centric Verification to Streamline Project Planning and Execution

2021 ◽  
Author(s):  
Reed Michele
Keyword(s):  
Early Development ◽  
Early Identification ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Project Planning ◽  
Capital Projects ◽  
Gas Industry ◽  
Construction Companies ◽  
Using Data ◽  
Set Up

There have been numerous calls for O&G companies to rethink the way they carry out capital projects. Various studies have highlighted that opportunities to enhance productivity exist from early development through to construction and handover to operations. Companies that are can realize these opportunities can complete projects safer and faster, reduce costs and quality issues, and improve schedule predictability. This paper presents data centric verification as a key enabler for such change, as it focusses on delivery of desired outcomes – the key to successful projects. This paper presents the rapid benefits that can be harvested, if the effort to put data centric verification in place is made. The following aspects are detailed to illustrate the benefits that are achievable: The wide variety of checking and confirmation activities on projects that frequently overlap, happen too late or don't focus on the correct aspects can be streamlined through a unified verification approach. Using a data centric approach to the set up and tracking of verification activities can support analytics to enable better planning and early identification of issues. Traceability in the data centric approach will enable quicker identification of root causes and remediations. Handover to operations moves from a document accumulation exercise to a data custody transfer. A typical O&G project is executed by a consortium of companies from owner/operators, engineering, procurement and construction companies, various suppliers and equipment manufacturers, etc. Data centric verification, if achieved, can only be through collaboration on a commonly agreed approach. Objectives/Scope Using data centric verification as an enabler to enhance project productivity from early development through handover. Methods, Procedures, Process This paper presents data centric verification as a key enabler for such change, as it focusses on delivery of desired outcomes – the key to successful projects. This paper presents the rapid benefits that can be harvested, if the effort to put data centric verification in place is made. The following aspects are detailed to illustrate the benefits that are achievable: The wide variety of checking and confirmation activities on projects that frequently overlap, happen too late or don't focus on the correct aspects can be streamlined through a unified verification approach. Using a data centric approach to the set up and tracking of verification activities can support analytics to enable better planning and early identification of issues. Traceability in the data centric approach will enable quicker identification of root causes and remediations. Handover to operations moves from a document accumulation exercise to a data custody transfer. Results, Observations, Conclusions The paper demonstrates the resulting requirements management and verification data models that can be established to enable the efficiency gains during project execution. Several example implementations of this data centric approach will be shared to validate the observed improvements. Novel/Additive Information Data centric verification is new to the Oil and Gas Industry. These Shell example projects are the first to implement this new approach within our supply chain.

Gravity-Fed Riserless Coiled Tubing Operations in Ultra-Deepwater: A Milestone Achievement for Riserless Intervention and Plug and Abandonment

2021 ◽  
Author(s):  
Andrea Sbordone ◽  
Bernt Gramstad ◽  
Per Buset ◽  
Rafael Rossi ◽  
Charlie Tramier ◽  
...  
Keyword(s):  
Deep Water ◽  
Oil And Gas ◽  
Open Water ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Norwegian Sea ◽  
Improve Efficiency ◽  
Coiled Tubing ◽  
First Time ◽  
Water Depths

Abstract In a continuous effort to reduce cost and improve efficiency, the Oil and Gas industry has been trying for the last 10 years to develop methods to perform subsea Coiled Tubing (CT) operations from a vessel and without a riser. In September 2020 a large campaign of Riserless Coiled Tubing (RLCT) coring was successfully executed in the Norwegian Sea, on the Mohns Ridge, approximately 330 nautical miles from the coast. The campaign was performed from a small Anchor Handler Tug Supply vessel, the Island Valiant. A total of 14 open water gravity-fed RLCT runs were executed in water depths between 2780 and 3085 m. The system performed extremely well and proved to be very robust, efficient and effective for these innovative operations. This was the first time that RLCT coring operations were completed without the use of a subsea injector, in the so-called gravity-fed mode, and in such ultra-deep water. This paper describes the project in detail, including the system setup used, a summary of the operations and the actual results achieved, before discussing future improvements and applications of the RLCT technology.

Well Control 4.0: Integration of a Transient Model in Automated Well Planning Workflows

2021 ◽  
Author(s):  
Bjoern-Tore Anfinsen ◽  
Inge Mosti ◽  
Waldemar Szemat-Vielma
Keyword(s):  
Oil And Gas ◽  
Negative Impact ◽  
Cost Optimization ◽  
Oil And Gas Industry ◽  
Planning System ◽  
Risk Level ◽  
Transient Temperature ◽  
Transient Model ◽  
Gas Industry ◽  
Well Control

Abstract Low oil prices are forcing the oil and gas industry to reduce the well construction cost. This calls for new and more efficient technologies and methods. Cost optimization may have negative impact on the risk level as less resources are available. Even with a strong focus on risk and new regulatory requirements, the well control risk level is not decreasing, but rather shows an increase. A new workflow has therefore been introduced in a collaborative cloud-based well planning system that combines the most advanced transient, multiphase engine with an automated procedure based on drillers method. The workflow will improve the quality of the well control planning as it will enable a simple way of automatic recalculation when the project context is changing. The data flow and quality control of data will also be improved and result in more up to date planning results. The automation of the process removes a huge amount of manual work that up to know has been required to keep the well control calculations synchronized with the project plan. New engine features unique to well control modeling like transient temperature and full compositional tracking adds resolution and accuracy to the well control planning results and helps deliver consistency in the results. The new workflow will deliver well control calculations with better resolution and accuracy with much less effort than what is normal today and should therefore help to reduce risk and cost associated with well planning.

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