Multi Zone Smart Well Completions Challenges in Highly Deviated Wells and Its Impact on Well Planning and Field Development

2021 ◽  
Author(s):  
Aqib Qureshi ◽  
Kushal Gupta ◽  
Salim Abdalla Al Ali ◽  
Yoshito Uchiyama ◽  
Rohit Singh Negi
Keyword(s):  
Development Strategy ◽  
Standard Procedure ◽  
Operational Parameters ◽  
Successful Operation ◽  
Field Development ◽  
Well Completion ◽  
Mandatory Requirement ◽  
Pass Through ◽  
Remedial Work ◽  
Well Completions

Abstract In multilayered reservoirs, major focus has been on the usage of smart well completion technologies to help improve recoveries, particularly with technological improvements and an increasing expanse of opportunities in more challenging and rewarding assets. The fundamental focus has been to design well completions that integrate several surface/subsurface sub zones and automate the flow control from each zone. In Multi zone Smart Completion Wells where significant investment is made to complete smart wells with remotely controlled inflow control valves (ICV), reservoir sweep & drain accessibilities becomes decisive when evaluating the efficiency of recovery and long-term field development strategy. Smart completion designs for multi-lateral wells present many challenges in terms of completion deployment and interventions in life of well. The complexity of operations increases with deviation, type of completion equipment, number of zones and planned interventions. In offshore, UAE a similar multilateral well was designed to be completed with 4 zone smart completion and had a mandatory requirement of accessibility to lower most drain (for future interventions) with the ability to plug the lower drain till future requirements arises. A solution is to utilize nipple & blanking plug in lower most drain, which was implemented in this well. Upon successful deployment of completion, plug was retrieved on coil tubing and lower drain accessibility was confirmed. However, during re-installation of blanking plug on coil tubing in deviated section, issues were encountered to pass through the ICV profiles. In attempts to pass through ICV profiles, blanking plug and running tool got disconnected from coil tubing, leaving the fish inside one of ICV valve. Several attempts were made to retrieve the blanking plug with rig on coil tubing without success by using thru-tubing fishing equipment options available in country. Well was suspend to work-out fishing strategy & evaluate availability of fishing equipment worldwide. Consideration was done for design and manufacture application specific fishing tools to perform workover with barge for such smart completion, as it includes a number of downhole components that makes its retrieval more challenging, and there are no standard procedure or provision in place to retrieve such complex completions in highly deviated section. A barge was mobilized with coil tubing, which performed the fishing operation as planned. Careful selection of equipment's, BHA and operational parameters resulted in successful retrieval of blanking plug & running tools. Accessibility to well was gain and confirmed. This paper presents the situation that was faced, the remedial work done to complete well, fishing operations and the subsequent factors considered for choice of equipment and operation on well. This paper concludes a detailed account of factors to consider for planning smart completions in horizontal multilateral wells & the successful fishing operation – an excellent example of how careful planning, dedicated project management, specialized design fishing tools, experienced personnel and a collaborative relationship between team's leads to a successful operation and prevented an extremely expensive workover of a high technology completion well.

High-Rate Gas Well Completions in Egypt's Mediterranean Sea: Tao Field Development Strategy and Case Histories

2010 ◽  
Author(s):  
Mohammed Abd Elwahab Mekawy ◽  
Vincent Fabien Rodet ◽  
Reza Kemal Mered ◽  
Ricardo Andres Gomez ◽  
Mehmet Parlar
Keyword(s):  
Mediterranean Sea ◽  
Development Strategy ◽  
High Rate ◽  
Case Histories ◽  
Gas Well ◽  
Field Development ◽  
Well Completions

Full Integrated Model as a Tool for Strategy Evaluation of the Greenfield

2021 ◽  
Author(s):  
Denis Nikolaevich Platon ◽  
Aidar Ramilovich Gatin ◽  
Matvei Nikolaevich Fomin ◽  
Nikita Sergeevich Korostelev
Keyword(s):  
Development Strategy ◽  
Mutual Influence ◽  
Simulation Models ◽  
Integrated Model ◽  
Injection Wells ◽  
Field Development ◽  
Well Completion ◽  
Stage Of Development ◽  
Drilling Rigs ◽  
Well Models

Abstract The main goal of this work is to evaluate and select the best strategy for the development of the field in the first stage of development. To solve this problem, a full-scale integrated model was created that takes into account the physics of the reservoir, wells and surface infrastructure, as well as their mutual influence. The integrated model was calculated for the full development of the asset. The integrated model of the A. Zhagrin field is based on three simulation models, well models and surface infrastructure, which are linked through an integrator program. All constituent parts of the model are configured to accurately reproduce their actual operation. Greenfield is characterized as active drilling, so the planned well count is modeled by replacing wells with "typical" well models, which are selected by taking into account the expected input flow rate, well design, well completion and well trajectory. Fields of the first stage of development are characterized by limitations related to oil transportation and treatment. These constraints are also specified and taken into account in the model The concept of surface infrastructure is formed depending on the potential production capabilities of the reservoir and has considerable variability. The total number of actual and planned wells in the field is more than 1,300, including more than 700 production wells and about 600 injection wells. All wells are ESP lifted. Considering infrastructure capacity constraints and requirements for optimal pipeline utilization, the use of different numbers of drilling rigs directly affecting the utilization of oil treatment and delivery facilities was evaluated. 29 main variations of the field development strategy until 2060 were formed and calculated, based on the integrated model. The main parameters of variation were the capacity of preparation facilities, the degree of oil separation, the scheme of product transportation, gas utilization capabilities, drilling rigs and subsurface equipment. All scenarios in the integrated model took into account constraints - on target bottomhole, wellhead and line pressures, in order to operate real facilities in accident-free mode. In the course of calculations, an optimal scenario was selected, which made it possible to increase oil production in 2021 by optimizing the transportation of produced products to the treatment facilities. This scenario formed the basis of the asset development strategy.

scholarly journals A Hybrid Artificial Intelligence Model to Predict the Elastic Behavior of Sandstone Rocks

2019 ◽  
Vol 11 (19) ◽  
pp. 5283 ◽  
Author(s):  
Gowida ◽  
Moussa ◽  
Elkatatny ◽  
Ali
Keyword(s):  
Poisson’S Ratio ◽  
Accurate Determination ◽  
Oil And Gas Industry ◽  
Poisson's Ratio ◽  
Elastic Behavior ◽  
Percentage Error ◽  
Ann Model ◽  
Field Development ◽  
Well Completion

Rock mechanical properties play a key role in the optimization process of engineering practices in the oil and gas industry so that better field development decisions can be made. Estimation of these properties is central in well placement, drilling programs, and well completion design. The elastic behavior of rocks can be studied by determining two main parameters: Young’s modulus and Poisson’s ratio. Accurate determination of the Poisson’s ratio helps to estimate the in-situ horizontal stresses and in turn, avoid many critical problems which interrupt drilling operations, such as pipe sticking and wellbore instability issues. Accurate Poisson’s ratio values can be experimentally determined using retrieved core samples under simulated in-situ downhole conditions. However, this technique is time-consuming and economically ineffective, requiring the development of a more effective technique. This study has developed a new generalized model to estimate static Poisson’s ratio values of sandstone rocks using a supervised artificial neural network (ANN). The developed ANN model uses well log data such as bulk density and sonic log as the input parameters to target static Poisson’s ratio values as outputs. Subsequently, the developed ANN model was transformed into a more practical and easier to use white-box mode using an ANN-based empirical equation. Core data (692 data points) and their corresponding petrophysical data were used to train and test the ANN model. The self-adaptive differential evolution (SADE) algorithm was used to fine-tune the parameters of the ANN model to obtain the most accurate results in terms of the highest correlation coefficient (R) and the lowest mean absolute percentage error (MAPE). The results obtained from the optimized ANN model show an excellent agreement with the laboratory measured static Poisson’s ratio, confirming the high accuracy of the developed model. A comparison of the developed ANN-based empirical correlation with the previously developed approaches demonstrates the superiority of the developed correlation in predicting static Poisson’s ratio values with the highest R and the lowest MAPE. The developed correlation performs in a manner far superior to other approaches when validated against unseen field data. The developed ANN-based mathematical model can be used as a robust tool to estimate static Poisson’s ratio without the need to run the ANN model.

Study on the Characteristics of Well Completion Technology in Deepwater Oil and Gas Field Development

2021 ◽  
Vol 3 (8) ◽  
pp. 70-72
Author(s):  
Jianbo Hu ◽  
◽  
Yifeng Di ◽  
Qisheng Tang ◽  
Ren Wen ◽  
...  
Keyword(s):  
Deep Water ◽  
Deep Sea ◽  
Oil And Gas ◽  
Gas Field ◽  
Marine Research ◽  
Field Development ◽  
Research Technology ◽  
Well Completion ◽  
Development Capacity ◽  
Exploration And Development

In recent years, China has made certain achievements in shallow sea petroleum geological exploration and development, but the exploration of deep water areas is still in the initial stage, and the water depth in the South China Sea is generally 500 to 2000 meters, which is a deep water operation area. Although China has made some progress in the field of deep-water development of petroleum technology research, but compared with the international advanced countries in marine science and technology, there is a large gap, in the international competition is at a disadvantage, marine research technology and equipment is relatively backward, deep-sea resources exploration and development capacity is insufficient, high-end technology to foreign dependence. In order to better develop China's deep-sea oil and gas resources, it is necessary to strengthen the development of drilling and completion technology in the oil industry drilling engineering. This paper briefly describes the research overview, technical difficulties, design principles and main contents of the completion technology in deepwater drilling and completion engineering. It is expected to have some significance for the development of deepwater oil and gas fields in China.

Offshore Gas Field Development Strategy and Flow Assurance Prediction and Optimization in Harsh Environment

2018 ◽  
Author(s):  
Humoud Almohammad ◽  
Abdullah Al-Derbass ◽  
Abdulaziz Alsubaie ◽  
Mohammed Bumajdad ◽  
Abdulaziz Al-Khamis ◽  
...  
Keyword(s):  
Development Strategy ◽  
Harsh Environment ◽  
Flow Assurance ◽  
Gas Field ◽  
Field Development

Data Analytics into Hydraulic Modelling for Better Understanding of Well/Surface Network Limits, Proactively Identify Challenges and, Provide Solutions for Improved System Performance in the Greater Burgan Field

2021 ◽  
Author(s):  
Qasem Dashti ◽  
Saad Matar ◽  
Hanan Abdulrazzaq ◽  
Nouf Al-Shammari ◽  
Francy Franco ◽  
...  
Keyword(s):  
Production Management ◽  
Planning Process ◽  
System Optimization ◽  
Development Planning ◽  
Operating Conditions ◽  
Flow Assurance ◽  
Operational Parameters ◽  
Field Development ◽  
Hydraulic Models ◽  
Surface Network

Abstract A network modeling campaign for 15 surface gathering centers involving more than 1800 completion strings has helped to lay out different risks on the existing surface pipeline network facility and improved the screening of different business and action plans for the South East Kuwait (SEK) asset of Kuwait Oil Company. Well and network hydraulic models were created and calibrated to support engineers from field development, planning, and operations teams in evaluating the hydraulics of the production system for the identification of flow assurance problems and system optimization opportunities. Steady-state hydraulic models allowed the analysis of the integrated wells and surface network under multiple operational scenarios, providing an important input to improve the planning and decision-making process. The focus of this study was not only in obtaining an accurate representation of the physical dimension of well and surface network elements, but also in creating a tool that includes standard analytical workflows able to evaluate wells and surface network behavior, thus useful to provide insightful predictive capability and answering the business needs on maintaining oil production and controlling unwanted fluids such as water and gas. For this reason, the model needs to be flexible enough in covering different network operating conditions. With the hydraulic models, the evaluation and diagnosis of the asset for operational problems at well and network level will be faster and more effective, providing reliable solutions in the short- and long-terms. The hydraulic models enable engineers to investigate multiple scenarios to identify constraints and improve the operations performance and the planning process in SEK, with a focus on optimal operational parameters to establish effective wells drawdown, evaluation of artificial lifting requirements, optimal well segregation on gathering centers headers, identification of flow assurance problems and supporting production forecasts to ensure effective production management.

Multistage Hydraulic Fracturing of the Tyumen Suite Reservoirs of Em-Yogovskoye Field: Frac-Design, Practice, Results

2021 ◽  
Author(s):  
Mikhail Ivanovich Samoilov ◽  
Vladimir Nikolaevich Astafyev ◽  
Evgeny Faritovich Musin
Keyword(s):  
Hydraulic Fracturing ◽  
Modular Design ◽  
West Siberia ◽  
Field Development ◽  
Well Completion ◽  
Multistage Hydraulic Fracturing ◽  
Sequence Of Events ◽  
Multi Stage ◽  
Development Plans ◽  
Operational Decision Making

Abstract The paper describes a system of approaches to the design and engineering support of multistage hydraulic fracturing: A method of developing multiple-option modular design of multistage hydraulic fracturing which is a tool for operational decision-making in the process of hydraulic fracturing.Building a Hydraulic Fracturing Designs Matrix when optimizing field development plans. The result was used to build decision maps for finding well completion methods and selecting a baseline hydraulic fracturing design. The paper also describes how the systematization of approaches, methodological developments, and decision templates can help in optimizing field development by drilling directional and horizontal wells followed by multi-stage hydraulic fracturing. The sequence of events and tasks that led to the development of the methodology, as well as its potential, is briefly described. The methodologies were developed during the execution of a hydraulic fracturing project at JK 29 reservoirs of the Tyumen Suite of Em-Yogovskoye field, after which they were applied in a number of other projects for the development of hard-to-recover hydrocarbon reserves in West Siberia.

Marginal Field Development Strategy: Malaysia Pm304 Cendor Field Success Story

2006 ◽  
Author(s):  
C.Y. McCants ◽  
Richard Hall ◽  
Brock Tuppeny ◽  
Keith Collins ◽  
Mohd. Khalid Jamiran and Stan Rae
Keyword(s):  
Development Strategy ◽  
Success Story ◽  
Field Development ◽  
Marginal Field

A geomechanical approach for sanding risk assessment applied to three field cases for completion optimisation

2010 ◽  
Vol 50 (1) ◽  
pp. 623 ◽  
Author(s):  
Khalil Rahman ◽  
Abbas Khaksar ◽  
Toby Kayes
Keyword(s):  
Decision Making ◽  
Petroleum Industry ◽  
Cost Effective ◽  
Development Planning ◽  
Control Measures ◽  
Sand Production ◽  
Field Development ◽  
Well Completion ◽  
Sand Control ◽  
Production Prediction

Mitigation of sand production is increasingly becoming an important and challenging issue in the petroleum industry. This is because the increasing demand for oil and gas resources is forcing the industry to expand its production operations in more challenging unconsolidated reservoir rocks and depleted sandstones with more complex well completion architecture. A sand production prediction study is now often an integral part of an overall field development planning study to see if and when sand production will be an issue over the life of the field. The appropriate type of sand control measures and a cost-effective sand management strategy are adopted for the field depending on timing and the severity of predicted sand production. This paper presents a geomechanical modelling approach that integrates production or flow tests history with information from drilling data, well logs and rock mechanics tests. The approach has been applied to three fields in the Australasia region, all with different geological settings. The studies resulted in recommendations for three different well completion and sand control approaches. This highlights that there is no unique solution for sand production problems, and that a robust geomechanical model is capable of finding a field-specific solution considering in-situ stresses, rock strength, well trajectory, reservoir depletion, drawdown and perforation strategy. The approach results in cost-effective decision making for appropriate well/perforation trajectory, completion type (e.g. cased hole, openhole or liner completion), drawdown control or delayed sand control installation. This type of timely decision making often turns what may be perceived as an economically marginal field development scenario into a profitable project. This paper presents three case studies to provide well engineers with guidelines to understanding the principles and overall workflow involved in sand production prediction and minimisation of sand production risk by optimising completion type.

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