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Feb, 09, Evaluating Efficiency of Multilateral Producing Wells in Bottom Water-Drive Reservoir with a Gas Cap by Distributed Fiber-Optic Sensors and Continuous Pressure Monitoring
Topic:  Evaluating Efficiency of Multilateral Producing Wells in Bottom Water-Drive Reservoir with a Gas Cap by Distributed Fiber-Optic Sensors and Continuous Pressure Monitoring

The main goal of the pilot job is to assess the risks of production by horizontal wells and multilateral wells with a close gas cap above and water layers beneath the main formation. The objectives are to monitor the total producing length of the wells using temperature and pressure surveillance. The results of monitoring were analyzed at different stages of development.

An analysis was carried out by combining pressure and temperature data obtained while monitoring the production of multilateral wells. The well properties were determined using RTA and PTA.

To assess the inflow profile, distributed temperature sensors in the wells were analyzed for the entire period of appraisal production. A feature of the research was the low contrast of temperature anomalies associated with fluid inflow. In addition, it was also revealed that the DTS absolute readings at the depth of the formation were affected by surface temperature, which required corrections and the use of relative readings in the calculations instead of absolute ones.

The main feature of the pressure analysis was the short period of production. With such well completion geometry and reservoir properties of the layer, the radial flow could not be achieved during the whole test period. Despite these limitations, the dynamics of the total producing length of the well was determined. The initial value of the producing length was about 70% of the drilled length, then there is a slight decrease after 7 to 10 months of well production.

By analyzing the fiber-optic temperature profile, an inflow profile was assessed. Based on the analysis of changes in relative temperature anomalies, the shares of inflow from the sidetracks were estimated.

Several memory temperature / pressure gauges set along the horizontal section were used as an additional data source to monitor well parameters during the whole period of production. The difference in their readings was due to, among other things, the average flow rate in the section between the sensors, which made it possible to give an independent assessment of the inflow profile.

Based on the results of the job performed, a number of risks and uncertainties were removed, including information on the total flowing horizontal length dynamics, which is a valuable input for full-field development planning. In addition, an express method of DTS data analysis has been developed for assessing the wellbore producing length without significant temperature changes associated with intervals of inflow.

Date: 9 February 2022, 14:00 (UTC+8)

Speaker: Vladimir Krichevsky, Leysan Surmasheva
Company: Sofoil
July 22, Base features of PolyGon - pressure/rate modeling software
Topic:  Base features of PolyGon - pressure/rate modeling software

Description:  Well studies should be facilitated with a simple and reliable software to model and interpret pressure and rate data. At this webinar we'll demonstrate basic features of out software PolyGon, performing data processing, PTA, RTA and PIT on field and synthetic datasets.

Date: 22 July, 2021, 16:00 (UTC+8)

Presenter: Vladimir Krichevsky

Company: Polykod
Language: English
April 13, PetroCup Introduction
Topic:  PetroCup Introduction

Introduction to PetroCup Immersive Learning Facility for Petroleum Asset Management.

The target audience is: asset managers, economists and procurement, surface facility engineers, well and reservoir engineers,  geologists, petrophysicists, drilling and workover engineers, production technologists,  simulation engineers, well test engineers, well and log analysts.

You will learn how a multidisciplinary team of asset managers and engineers can test and develop their skills in a fully automated virtual reality !

Date: 13 April, 10:00  (UTC +3)

Presenter: Dr. Artur Aslanyan
Company: Nafta College
March 25, Tracers vs. Pulse Code Testing (PCT): How to scan your reservoir fast and accurately
Topic:  Tracers vs. Pulse Code Testing (PCT): How to scan your reservoir fast and accurately

Understanding cross-well connectivity  in a reservoir is very important both for greenfields and brownfields to properly plan drilling, well interventions, improve sweep efficiency and as a result - to increase ultimate recovery. There are two main technologies to reveal it: chemical tracer injection (for waterflood projects) and pressure interference testing. In this webinar we compare pros and cons of these technologies, demonstrating how they perform on synthetic fields with typical reservoir complications: compartmentalization, vertical heterogeneity and non-uniform waterflood pattern.

Date: 25 March, 15:00  (UTC +8)

Dr. Danila Gulyaev
Company: Sofoil
March 10, Blind-Test Validation for pressure-flowrate predictive models with an example of MRT
questions after webinar.

1) What is the regularization algorithm?

2) How do you deal with multiphases?

3) ​considering that deconvolution is an analytical approach then the deconvolution for th eentire field with 20 wells should not cost a lot of computing, ​right?
July 9, Mastering your skills an overview
Topic:  Mastering your skills an overview

Oil Fields from Seismic surveys through drilling, production, reservoir management to the gas station are complex engineering endeavors. You can't apply Newton's Physics to drill a well 5-10 kilometres below ground and hit your target within a meter or less. The Petrophysics and the fluid behavior in such environment are non-Newtonian.

Oilfields, however, have been discovered and produced and still supplying the world with about 100 million barrels a day, that is about 200 gallons per person on the Planet Earth per year.

Please join me with NAFTA College engineers to share with you the latest in technology in Oil Field Management.  NAFTA College Teams have developed PetroCup, a tool to apply and sharpen your skills, get immediate feedback of your strategy, and prioritize your operations by analyzing all key variables according to their impact on your NPV.  All that is done from the comfort of your office, or your home , and with your team, or compete with other teams for the best results.

09 July, 2020, 12:00 (UTC+8)

Dr. Jamal Barghouti
Company: Nafta College
March 10, Blind-Test Validation for pressure-flowrate predictive models with an example of MRT
Topic:  Blind-Test Validation for pressure-flowrate predictive models with an example of MRT

When dealing with advanced data processing technologies, claiming to build predictive models - there are several ways to test them, using modelled or field data of various complexity. Vladimir Krichevsky will tell the story of a major oil company proving the abilities of Multiwell Retrospective Testing technology with multi-step testing, including both synthetic cases and field data examples.

Date: 10 March, 15:00  (UTC +8)

Presenter: Vladimir Krichevsky
Company: Sofoil
February 16 ,Prime Analysis as the consolidating analytical tool for Production Data Analysis
Topic: Prime Analysis as the consolidating analytical tool for Production Data Analysis

Prime Analysis is a high-level analysis based on set of Production Performance Indicators derived from primary production history data (such as flow rates, formation and bottom-hole pressure, pressure tests, production logs). It focuses on wells and field areas which are dragging behind the expected recovery or pressure support targets due to integrity issues, poor connectivity or inaccurate understanding of the reservoir around these wells. This is a primary tool to select the candidates for additional data acquisition.

Date: 16 February 2021, 15:00 (UTC+8)

Presenter: Marat Garnyshev
Company: Sofoil
November 6, 2020, Value Protection and Enhancement Through Sound Reservoir Management
Topic: Value Protection and Enhancement Through Sound Reservoir Management

Sound reservoir management is compulsory to maximize field recovery throughout its life. Strategizing the data acquisition while recognizing its value of information and utilizing latest technology are the key enablers to assure optimum field decision and development. Understanding reservoir behavior and maximizing information provided by the acquired data are very important. This webinar elaborates the concept and application of integrated Reservoir Management to maximize the Asset’s value. Number of case studies will be discussed including managing low infectivity problem, identifying by-passed oil and deciphering inter-wells connectivity with latest technology available in industry with successful follow up results.

Date: 06 November 2020, 15:30 (UTC+8)

Presenter: Ronny Gunarto
Company: PTTEP
October 8, 2020, Flow control devices for smart wells
Topic:  Flow control devices for smart wells.

In this lecture the most popular flow control devices are described: ICD, AICD, hydraulic and full electric valves. Main features and limitations are considered, including technical specifications and prices.

Date: 8 October, 15:00 (UTC+8)

Presenter: Andrey Arbuzov
Company: Tota
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