Automation of Formation Tops Estimation Dramatically Reduces Well Planning Process Duration

2021 ◽  
Author(s):  
Rail Salimov ◽  
Javier Torres ◽  
Yousif Al Katheeri ◽  
Yousef Alhammadi ◽  
Ahmed Abdelrahman
Keyword(s):  
Open Source ◽  
Planning Process ◽  
Computing Time ◽  
Value Added ◽  
Target Surface ◽  
Field Development ◽  
Executable File ◽  
Well Trajectory ◽  
Automation Project ◽  
Similar Triangles

Abstract Aiming to make the well planning process leaner and agile focusing on duration reduction without compromising quality of deliverables, automation opportunities have been identified within the multi-discipline iterations. The two key criteria considered for the selection of the automation project were: Minimum deployment effort and Maximum value added in efficiency. The initial project objective was to calculate formation tops for a well engineer without requiring the intervention of a geoscientist using commercial software. The methodology utilized is the following: 1. Inputs: Well trajectory and Surfaces. 2. Process: The algorithm finds intersections between surfaces and well trajectory. Surfaces and trajectory are represented as a set of XYZ points. To find the intersection, the software iterates through each point of the trajectory from the top, comparing the depth of the projection to the target surface. The projected depth to the surface is found by 2D interpolation of the surface. Once the trajectory point becomes deeper than the surface projection, the intersection is estimated using geometrical considerations of similar triangles. 3. Deliverables: Estimated formation tops for the given trajectory. 4. Results: Simple in-house developed software enhanced well planning workflow in an Offshore Green Field. The software converted to single executable file and can be run on any device without the open-source software installed. Very accurate results achieved with proposed algorithm with a negligible difference of 0.5 feet with the geoscience traditional software. Well planning duration reduced from average 1 week to 1 or 2 days. The workload for well engineers and the asset team has been dramatically reduced. Reduction of the number of commercial geoscience software licenses required. Way forward: A test with a slightly modified code was used to generate formation tops for more than 400 well in a Long-Term Field Development Plan project for a Brown Field during feasibility study. Upscale to all the Fields within the organization. Improve User Interface for better adoption. Include more formats for both, trajectories, and surfaces. Reduce computing time. This project represents the first initiative in the organization aiming to automate the well planning process. Overall, it represents the beginning of a journey where multiple opportunities for automation can be achieved using an open-source coding software that allows any engineer with little to no experience coding to being able to generate solutions to address daily challenges.

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.

Incorporating Economic Decisions into Reservoir Simulation to Support Accurate and Efficient Optimization and Analysis of Field Development Strategies

2021 ◽  
Author(s):  
Jim Browning ◽  
Sheldon Gorell
Keyword(s):  
Reservoir Simulation ◽  
Value Added ◽  
Simulation Models ◽  
Operating Conditions ◽  
Conditional Logic ◽  
Economic Optimization ◽  
Field Development ◽  
Production Constraints ◽  
Automated Method ◽  
Economic Decision Making

Abstract Economic optimization of a reservoir can be extremely tedious and time consuming. It is particularly difficult with many wells, some of which can become non-economic within the simulated time period. These problems can be mitigated by: 1) analyzing the results of a simulation once it has run, or 2) applying injection or production constraints at the well level. An example of option 1 would be integration with a spreadsheet or economic simulation package after the simulation has run. An example of option 2 would be to set a maximum water cut, upon which the well constraints could be changed, or the well could be shut in within the simulation. Both of these methods have drawbacks. If the goal is to account for how changes in a well operating strategy affects other wells, then analysis after the fact requires many runs to sequentially identify and modify well constraints at the correct times and in the correct order. In contrast, applying injection and production constraints to wells is not the same as applying true economic constraints. The objective of this work was to develop an automated method which includes economic considerations within the simulator to decrease the amount of time optimizing a single model and allows more time to analyze uncertainty within the economic decision making process. This study developed automated methods and procedures to include economic calculations within the context of a standard reservoir simulation. The method utilized modifications to available conditional logic features to internally include and export key economic metrics to support appropriate automatic field development changes. This method was tested using synthetic models with different amounts of wells and operating conditions. It was validated using after the fact calculations on a well by well basis to confirm the process. People costs are always among the most significant associated with running a business. Therefore, it is imperative for people to be as efficient and productive as possible. The method presented in this study significantly reduces the amount of time and effort associated with tedious and manual manipulations of simulation models. These savings enable an organization to focus on more value-added activities including, but not limited to, accurately optimizing and estimating of uncertainty associated decisions supported by reservoir simulation.

Creating Open-Source Interactive Articles for the Wider Publics

2015 ◽  
pp. 407-429
Author(s):  
Shalin Hai-Jew
Keyword(s):  
Open Access ◽  
Open Source ◽  
Value Added ◽  
Data Sets ◽  
Authoring Tools ◽  
Levels Of Abstraction ◽  
Digital Photographs ◽  
Multiple Audiences ◽  
Electronic Games ◽  
Different Levels

A core form of the international sharing of research and analysis is done through articles, both those presented in live conferences and those published in any number of journals. Interactive articles integrate various elements to the basic text: hyperlinks; immersive simulations; electronic games; data sets; knowledge collections; digital photographs; multimedia; integrated wikis and blogs; and other aspects. These value-added pieces that build exploration, experience, and interactivity, are enabled by current authoring tools and Web servers and open-source contents. Enriched articles often encourage return engagements, and their open-source publishing often leads to greater levels of citations and readership. These enable the design of a work for multiple audiences, with opt-in sections for different levels of readers, for example. Interaction enables opportunities for more reflection, recursiveness, and understanding a topic from multiple angles and different levels of abstraction. Interactive articles tend to appear in open-source (or at least open-access) publications online, which enables access by wider reading publics and machine-searchability and often wider citations.

SUB-SURFACE UNCERTAINTY IN OIL FIELDS: LEARNINGS FROM EARLY PRODUCTION OF LEGENDRE OIL FIELDS

2003 ◽  
Vol 43 (1) ◽  
pp. 401
Author(s):  
R. Seggie ◽  
F. Jamal ◽  
A. Jones ◽  
M. Lennane ◽  
G. McFadzean ◽  
...  
Keyword(s):  
Planning Process ◽  
Development Planning ◽  
Oil Field ◽  
Production Performance ◽  
Oil Fields ◽  
High Rate ◽  
Secondary Development ◽  
North West ◽  
Field Development ◽  
Small Primary

The Legendre North and South Oil Fields (together referred to as the field) have been producing since May 2001 from high rate horizontal wells and had produced 18 MMBBL by end 2002. This represents about 45% of the proven and probable reserves for the field.Many pre-drill uncertainties remain. The exploration and development wells are located primarily along the crest of the structure, leaving significant gross rock volume uncertainty on the flanks of the field. Qualitative use of amplitudes provides some insight into the Legendre North Field but not the Legendre South Field where the imaging is poor. The development wells were drilled horizontally and did not intersect any fluid contacts.Early field life has brought some surprises, despite a rigorous assessment of uncertainty during the field development planning process. Higher than expected gas-oil ratios suggested a saturated oil with small primary gas caps, rather than the predicted under-saturated oil. Due to the larger than expected gas volumes, the gas reinjection system proved to have inadequate redundancy resulting in constrained production from the field. The pre-drill geological model has required significant changes to reflect the drilling and production results to date. The intra-field shales needed to be areally much smaller than predicted to explain well intersections and production performance. This is consistent with outcrop analogues.Surprises are common when an oil field is first developed and often continue to arise during secondary development phases. Learnings, in the context of subsurface uncertainty, from other oil fields in the greater North West Shelf are compared briefly to highlight the importance of managing uncertainty during field development planning. It is important to have design flexibility to enable facility adjustments to be made easily, early in field life.

Surface Casing Cum Production Casing Well Design – Extreme but Techno-economically Acceptable Approach

2021 ◽  
Author(s):  
M Hatta M Yusof ◽  
Rahimah A Halim ◽  
Nurfaridah Ahmad Fauzi ◽  
Ahgheelan Sella Thurai ◽  
M Zulfarid Khalid ◽  
...  
Keyword(s):  
Low Cost ◽  
Oil Price ◽  
Significant Component ◽  
Field Development ◽  
Well Integrity ◽  
Well Design ◽  
Open Hole ◽  
Well Trajectory ◽  
Fit For Purpose

Abstract 2020 marks another challenging year for O&G sector, with the operators being in an uphill battle to survive the plunging oil price. With CAPEX rationalization underway, future field development may only be prospective via implementation of low-cost Field Development Plan (FDP). As well cost is a significant component of development CAPEX, low well cost must be pursued, by designing fit-for-purpose wells. For relatively shallow (≈2000 m-MD in meterage drilled) wells, a simple well design consisting of only two-hole sections (excluding Conductor) shall be considered. This design approach though, may require the Surface Casing to also be the Production Casing (if only Production Liner will be ran in the production hole section or if open hole completion is feasible or if cemented monobore completion strategy is adopted). This aspect of casing design (having Surface cum Production Casing) does indeed pose well integrity concerns as the quality of cement behind the Surface cum Production Casing is uncompromisable to ensure no gas can breach to surface. This paper discusses the design measures than can be incorporated into the well trajectory, cementing plan, and production surveillance in order to support the feasibility of Surface cum Production Casing concept.

Free and Open Source Creating Miracle with EIS

2017 ◽  
Vol 8 (4) ◽  
Author(s):  
Subodh Kesharwani
Keyword(s):  
Open Source ◽  
Open Source Software ◽  
Source Code ◽  
Computer Software ◽  
Value Added ◽  
Copyright Holder ◽  
For Profit ◽  
Open Collaboration ◽  
Collaborative Community

Open-source software (OSS) is computer software with its source code made accessible with a license in which the copyright holder provides the rights to cram, revolutionize, and assign the software to everyone and for any insistence. Open-source software may be time-honored in a collaborative community form. The Group who had initiated opensource software is an obvious example of open collaboration. Open-source software at present is expansively used both as self-governing applications and as components in non-open-source applications. Many independent software vendors (ISVs), value-added resellers (VARs), and hardware vendors (OEMs or ODMs) make use of open-source frameworks, modules, and libraries within their brand-named, for-profit products and services.

scholarly journals SW-VHDL Co-Verification Environment Using Open Source Tools

Electronics ◽  
2020 ◽  
Vol 9 (12) ◽  
pp. 2104
Author(s):  
Maria Muñoz-Quijada ◽  
Luis Sanz ◽  
Hipolito Guzman-Miranda
Keyword(s):  
Open Source ◽  
Software Systems ◽  
Computer Language ◽  
Executable File

The verification of complex digital designs often involves the use of expensive simulators. The present paper proposes an approach to verify a specific family of complex hardware/software systems, whose hardware part, running on an FPGA, communicates with a software counterpart executed on an external processor, such as a user/operator software running on an external PC. The hardware is described in VHDL and the software may be described in any computer language that can be interpreted or compiled into a (Linux) executable file. The presented approach uses open source tools, avoiding expensive license costs and usage restrictions.

scholarly journals Integrated Field Development Plans of Akkas Gas Field

2020 ◽  
Vol 10 (3) ◽  
pp. 102-122
Author(s):  
Dr. Jalal A. Al-Sudani ◽  
Eng. Adnan N. Sajet ◽  
Eng. Jalal Ahmed ◽  
Eng. Mohamed Enad ◽  
Dr. Abdul-Hussain H. Al-Shibly ◽  
...  
Keyword(s):  
Net Present Value ◽  
Planning Process ◽  
Development Planning ◽  
Gas Production ◽  
Recovery Factor ◽  
Western Desert ◽  
Discounted Cash Flow ◽  
Gas Field ◽  
Field Development ◽  
Development Plans

Akkas gas field is the biggest natural gas field in Iraq that is located in the western desert area. The field contains around (9 BSCF) of approved gas reserve from the conventional rock source. This paper presents field development planning process combined with economic analysis comprises, the number of wells that yields in maximum net present value (NPV), the recovery factor and raw gas production rates for the total number of suggested wells that have been estimated, as well as the cumulative gas produced with time. The development plans were elaborated concerning different types of well geometries and operational constraints. Full comparison analysis for all presented plans regarding NPV, recovery factor, discounted cash flow versus production time, forecasted production rate, as well as forecasted cumulative production with time have been presented. Sensitivity analysis has been made to determine well and reservoir controlling parameters that leads for best operating field development plans. The study shows the effectiveness of horizontal well type compared with vertical wells; as well as, the effect of reservoir permeability on field development plans, the results show that the field could be operated at target plateau rates of (250, 500 and 750 MMSCF/D). It also shows the superior effect of stimulation processes in increasing the NPV and field recovery factor using less number of wells

scholarly journals Biobtree: A tool to search and map bioinformatics identifiers and special keywords

F1000Research ◽  
2020 ◽  
Vol 8 ◽  
pp. 145
Author(s):  
Tamer Gur
Keyword(s):  
Web Services ◽  
Open Source ◽  
Resource Usage ◽  
Web Interface ◽  
Bioinformatics Tool ◽  
Link Type ◽  
As Species ◽  
Storage Resource ◽  
Executable File ◽  
And Storage

Biobtree is a bioinformatics tool to search and map bioinformatics datasets via identifiers or special keywords such as species name. It processes large bioinformatics datasets using a specialized MapReduce-based solution with optimum computational and storage resource usage. It provides uniform and B+ tree-based database output, a web interface, web services and allows performing chain mapping queries between datasets. It can be used via a single executable file or alternatively it can be used via the R or Python-based wrapper packages which are additionally provided for easier integration into existing pipelines. Biobtree is open source and available at GitHub.

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