First Open Hole Horizontal Near HP/HT Critical Sour Gas Wells Completion in Indonesia: Lesson Learned from BD Field Development Project in Kujung Formation

2017 ◽  
Author(s):  
M. S. Nurdin ◽  
M. O. Etuhoko ◽  
D. R. McKen ◽  
J. Lian ◽  
A. Syapari ◽  
...  
2014 ◽  
Author(s):  
Ardian Nengkoda ◽  
Mofeed Awwami ◽  
Xiaolong Cai ◽  
Jamal Mufleh ◽  
Bader Harbi ◽  
...  

2014 ◽  
Author(s):  
Ardian Nengkoda ◽  
Mofeed Awwami ◽  
Xiaolong Cai ◽  
Jamal Mufleh ◽  
Bader Harbi ◽  
...  

2021 ◽  
Author(s):  
Charlotte Eliasson ◽  
Ove Braadland ◽  
Håvard Kaarigstad ◽  
Anne-Mette Mathisen ◽  
Zalpato Ibragimova ◽  
...  

Abstract For the Johan Castberg field development project, injector wells are important for achieving high production and overall high recovery factors. Injectivity has become more important due to limitations in injection pressures and required control of fracture growth. Securing injectivity has been identified as one of the project’s main risks, making drill-in fluid and breaker fluid system qualification a vital parameter for success. Operational procedures and completion design also affect the effectiveness of breaker fluid placement and, thus, the overall injectivity of the well. In this paper, we present a cross-disciplinary systematic approach for the reservoir drill-in fluid and breaker fluid qualification to ensure injectivity in these wells. Two wells were selected for covering the expected pressure and temperature range of the field in an environmentally sensitive area. Two independent fluid systems were designed, where the bridging material consisted of either sized salt particles or calcium carbonate particles. The open hole completion design has been optimized for an effective breaker fluid placement, using a modified gravel pack system with a wash pipe. The displacement sequence has been optimized for effective deployment. An extensive laboratory test matrix for both the reservoir drilling fluid (RDF) and breaker fluid system was established, including thorough analysis of the interaction between the deposited filter cake and the breaker fluid system. The RDF and breaker fluid formulation optimization was performed whilst keeping in mind the operational requirements and the well’s future injectivity The presented results show successful qualification of two independent fluid and breaker fluid systems where filter cake breakthrough is achieved within the desired time frame. The fluid systems in combination with the lower completion design and operational procedures ensure maximal reservoir exposure of the breaker fluid solution and enable rapid deterioration of the filter cake.


Author(s):  
R.A. Gasumov ◽  
◽  
E.R. Gasumov ◽  

The article discusses the modes of movement of gas-liquid flows in relation to the operating conditions of waterlogged gas wells at a late stage of field development. Algorithms have been developed for calculating gas well operation modes based on experimental work under conditions that reproduce the actual operating conditions of flooded wells of Cenomanian gas deposits. The concept of calculating the technological mode of operation of gas wells with a single-row elevator according to the critical velocity of the upward flow is considered based on the study of the equilibrium conditions of two oppositely directed forces: the gravity of water drops directed downward and the lifting force moving water drops with a gas flow directed upward. A calculation was made according to the method of the averaged physical parameters of formation water and natural gas in the conditions of flooded Cenomanian gas wells in Western Siberia. The results of a study of the dependence of the critical flow rate of Cenomanian wells on bottomhole pressure and diameter of elevator pipes are presented.


2021 ◽  
Author(s):  
Adil Mukanov ◽  
Asset Zhumadil

Abstract The 74th step of "100 Concrete Step of Nation Plan" initiated by the first president of the Republic of Kazakhstan (RoK) Nursultan Nazarbayev states that Kazakhstani reserves reporting system must be changed to the international standards. One of them actively proposed is the SPE-PRMS. Therefore, the main goal of the paper is to show challenges of the transition, discuss possible problems, their solution and, eventually, advantages for the companies. In the paper the main aspects of the current State Committee of Reserves (SCR) system or well-known as GKZ system inherited from the Soviet system and used in Kazakhstan are reported. Especially, we try to highlight the reserves categories of A, B, C1 and C2 and their impact on further field development in details. Also SPE-PRMS and SEC rules are shown in terms of differences and similarities with the current system. Importantly, authors demonstrate how the SPE-PRMS standards are wide-spread around the globe. Finally, details of planned shift, some recommendations and simplification of reporting process are exhibited. As the result of the study the following points are investigated. Firstly, what will be with reports just recently approved by the SCR. Especially, for the big fields whose preparation takes up to several years. Secondly, what the frequency is for the reporting. Thirdly, whether the reports will be handled through several approval stages or just submitted. Moreover, how close to SPE-PRMS the new system should be adopted taking into account Kazahstani realities and if the reports should be composed in English along with Russian, since the main purpose of the transition is to be clear and transparent for the foreign investors. Otherwise, unfamiliar language and big deviation from the well-known standards may ruin the efforts. Despite the complexity of these issues the benefits of the new system are obvious and there are several reasons. The main advantage is that the SPE-PRMS is all about economically recoverable reserves without any ties with fixed recovery factor. In addition, report is done in short time and less volume. Finally, if the norm of the report's submission without going to tedious approval process is accepted, that will ease work of the subsoil users’ because it accelerates further preparation of field development project. The study is done due to recent changes of the RoK subsoil usage regulations, where the requirement for reserves reporting system's transition to the new international standards is mentioned. However, the issue is not much highlighted in technical publications from the operating companies’ point of view. Thus, having experience with GKZ, SPE-PRMS and SEC systems the authors take this opportunity to show challenges and benefits of the decision.


2021 ◽  
Author(s):  
Kamlesh Kumar ◽  
Varun Pathak ◽  
Pankaj Agrawal ◽  
Zaal Alias ◽  
Tushar Narwal ◽  
...  

Abstract Effective gas utilization is critical to any gas injection development project to maximize recoveries for a given purchase of make-up gas, whilst reducing the Green Gas House (GHG) emissions. This paper describes the use of a fully implicit Integrated Production System Model (IPSM) for two inter-connected production system networks, coupling multiple, critically sour oil reservoirs undergoing Miscible Gas Injection (MGI) for Enhanced Oil Recovery (EOR) using produced sour gas from oil and condensate fields in South Oman. The IPSM model links sixteen reservoir models with varying levels of complexities to the facilities network. Complexities in the facilities include multiple nodal constraints that necessitate the use of an Equation of State model (EOS). The IPSM model honors the gas balance implicitly. Gas flood optimization includes prioritizing low GOR production wells (at reservoir and well level) whilst maintaining reservoir pressure above Minimum Miscibility Pressures (MMP). Development schedule optimization also helps in optimizing the compressor size, the key Capex component. Compositional modeling allows continuous tracking of souring levels at different nodes, providing integrity status of overall production system network. The current IPSM model helps in optimization of schedule for the phased development of the oil reservoirs and eventually the most efficient gas utilization. This has enabled low pressure operation in some reservoirs providing oil at very low unit technical cost while waiting for gas availability. Compositional tracking for H2S helps in operating the facilities within design limits whilst planning future developments to cater to this design. Some key parameters can be parameterized for quick sensitivity analysis for an informed decision making for business opportunities. The production potential of the system is also tracked to ensure there is a cushion in the system to deal with any unexpected changes. This feature helps in planning and optimizing the scheduled turn-around activities for these two inter-connected production system networks. The novelty of this work is collaboration across multiple disciplines, especially the surface and subsurface because of complex interactions between facilities constraints and reservoir performance (associated with produced gas reinjection). Compositional tracking and injection gas apportionment across multiple reservoirs is key to the overall value maximization in this complex development.


2021 ◽  
Author(s):  
Prasad Kunnathully Prabhakaran ◽  
Cibu Varghese ◽  
Faris Ragheb Kamal

Abstract As part of a green field development project for ADNOC offshore, NPCC here in after called as "contractor", successfully completed installation of an oil and gas processing super complex at offshore Abu Dhabi. This super complex consisted of four large interconnected platforms of different functionalities and an accommodation platform. Associated flare structures and interconnecting bridges were also installed as part of this project. Weights of the topsides in this project were varying from 7,000MT to a ∼32,000 MT. All these topsides were installed by float-over method using contractors own cargo /launch barge fleet. Gas treatment platform topside installed as part of the above project is the world's heaviest single-module topside Installed by float-over on a fixed steel jacket. Float-over is the process of installing the topside on a preinstalled jacket by ballasting and/or by other methods of load transfer such as hydraulic jacks. This installation method is widely used for heavy topsides, due to its cost effectiveness and efficiency. By float over installation method, the topside can be installed as a single integrated unit after completion of all hookup and commissioning works onshore. This paper outlines installation engineering challenges during EPC phase for the gas treatment platform topside. Design of this topside went through phenomenal changes in terms of its size and weight during EPC phase and posed several challenges to install this unit as a single module. This paper presents the installation method, and various parameters considered during installation and also includes discussion on selection of float-over barge, importance of weight control & layout design, finalization of topside support height on barge and installation aids. This paper also presents various installation engineering analyses required during design stage. Float-over installation of the gas treatment platform was carried out by the conventional load transfer method (by ballasting) and using normal spread mooring arrangement.


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