Improving Well and Reservoir Management Practice Through New Flow Control Philosophy that Prolongs the Life of Production Wells Affected by Water Breakthrough in A Giant Carbonate Oil Field, Abu Dhabi, United Arab Emirates

2021 ◽  
Author(s):  
Jhon Robert Ortiz Requena ◽  
Maryvi Yabet Santiago Martinez ◽  
Fatmah Mohamed Alshehhi ◽  
Fareed Ahmad Daudpota ◽  
Ahmed Mohamed Fawzy
Keyword(s):  
United Arab Emirates ◽  
Flow Analysis ◽  
Reservoir Management ◽  
Oil Wells ◽  
Critical Flow ◽  
Water Breakthrough ◽  
Production Wells ◽  
Water Cut ◽  
Natural Life ◽  
Field Production

Abstract X Field located in the United Arab Emirates has been developed since 1970's by waterflooding as secondary recovery strategy. As water front advances into oil bank, the well operation practice commonly adopted in many fields for oil wells cutting water has consisted in reducing choke aperture in an attempt to control the water cut trend. However, in wells producing moderate to high water cut, this practice has proven to generate excess water settling in the bottom of the wellbore leading to premature inactivation of the wells. The reservoir Z in the north of X Field, is a black oil block operated by peripheral and pattern waterflooding. The production wells have been operating by natural lifting since first oil and will continue in natural flow until the Artificial Lift projects are commissioned within a few years. Meanwhile, the field production plateau has been increased arising challenges of production sustainability due to higher risk of acceleration of water breakthrough and consequently higher number of wells becoming inactive earlier. This led to re-assess the Well and Reservoir management strategy to define improved practices oriented to maximize the natural life cycle of wet wells and ensure the compliance of the field production quota. As a result, a new well management approach was devised and adopted to identify and optimize at the earliest stage, wells potentially affected by water loading mismanage. Conceptually, this new practice consisted in comprehensively analyzing well operating conditions, which ultimately generated a flow operating window that improved the multiphase flow performance in wellbores, minimized water slippage avoiding it to settle down and its associated problems, whilst respecting the compliance of technical guidelines for optimum reservoir management. Based on observations and data gathered from portable testing jobs, saturation logs, PLT and production monitoring; a methodology referred in this work as Critical Flow Analysis, has been successfully implemented in several naturally flowing wells with water cuts ranging from 15 – 40 % in Reservoir Z in X Field, which resulted in prolonged natural life, extra oil recovered, and avoided the negative impact of inactive string count on the Field Management KPI. The Critical Flow analysis has been a comprehensive well management evaluation and operation philosophy in Reservoir Z which helped to manage more efficiently and in cost-saving fashion the performance of oil wells located in high risk areas, in addition to contribute with stablishing best practices for well and reservoir management that could be extended to analog fields in the area.

Innovations of Gas Lift in Prolific, Long-perforations, and Multilayered Wells, Case Study in Sudan

2016 ◽  
Author(s):  
Xueqing Tang ◽  
Lirong Dou ◽  
Ruifeng Wang ◽  
Jie Wang ◽  
Shengbao Wang ◽  
...  
Keyword(s):  
High Water ◽  
Water Breakthrough ◽  
Start Up ◽  
Production Wells ◽  
Decline Curves ◽  
High Water Cut ◽  
Water Cut ◽  
Gas Lift

ABSTRACT Jake field, discovered in July, 2006, contains 10 oil-producing and 12 condensate gas-producing zones. The wells have high flow capacities, producing from long-perforation interval of 3,911 ft (from 4,531 to 8,442 ft). Production mechanisms include gas injection in downdip wells and traditional gas lift in updip, zonal production wells since the start-up of field in July, 2010. Following pressure depletion of oil and condensate-gas zones and water breakthrough, traditional gas-lift wells became inefficient and dead. Based on nodal analysis of entire pay zones, successful innovations in gas lift have been made since March, 2013. This paper highlights them in the following aspects: Extend end of tubing to the bottom of perforations for commingled production of oil and condensate gas zones, in order to utilize condensate gas producing from the lower zones for in-situ gas lift.Produce well stream from the casing annulus while injecting natural gas into the tubing.High-pressure nitrogen generated in-situ was used to kick off the dead wells, instead of installation of gas lift valves for unloading. After unloading process, the gas from compressors was injected down the tubing and back up the casing annulus.For previous high water-cut producers, prior to continuous gas lift, approximately 3.6 MMcf of nitrogen can be injected and soaked a couple of days for anti-water-coning.Two additional 10-in. flow lines were constructed to minimize the back pressure of surface facilities on wellhead. As a consequence, innovative gas-lift brought dead wells back on production, yielding average sustained liquid rate of 7,500 bbl/d per well. Also, the production decline curves flattened out than before.

scholarly journals The Application of Diagnostic Plots to Evaluate Water Flooding

2020 ◽  
Vol 1 (1) ◽  
pp. 36
Author(s):  
Ratna Widyaningsih ◽  
Muhamad Zamzam Istimaqom ◽  
Hizballah Nidaulhaq ◽  
Atma Budi Arta
Keyword(s):  
Production Optimization ◽  
Water Flooding ◽  
Diagnostic Plots ◽  
Plot Analysis ◽  
Water Breakthrough ◽  
Production Wells ◽  
Light Oil ◽  
Current Production ◽  
Cumulative Production ◽  
Water Cut

To analyze production optimization using waterflood, several types of diagnostic plots are needed to determine the response to using waterflood. If you have analyzed 1 plot, it is necessary to conduct a comprehensive analysis to evaluate its success rate by combining it using another plot analysis. The X-Min Field is a field that produces light oil and is managed by the Asset Optimization SLO North PT. Chevron Pacific Indonesia. This field was discovered in 1959 and started to be produced in 1966. Currently, 100 wells have been drilled with 37 active wells from 43 production wells, active injector wells are 18 out of 19, inactive wells 30, 4 wells have been plugged in, and there are 4 active wells that produce gas. The number of OOIPs in this field is 593 MMBO with cumulative production reaching 283.7 MMBO and Recovery Factor reaching 47.7%. In 2017 it was noted that the current production in December 2017 amounted to 5,374 BOPD / 121,264 BFPD or in other words the water cut reached 96.6%. Meanwhile, the amount of injection used to optimize this field is 144,103 BWIPD. Reservoirs in this field have 4 reservoirs namely Res-1, Res-2, Res-3, and Res-4 wherein each reservoir there are several grains of sand optimized using waterflood. There was 8 sand analyzed, including Sand Asyique, Sand Bajubaru, Sand Cemangad, Sand Emakpintar, Sand Fantamantap, Sand Gulungulung, Sand Harikita, and Special Sand. Closes the producer indicated premature water breakthrough. General recommendations given to various sands include adding or subtracting, both injectors and producers based on the response of each sand to water flooding.

Preventing Proppant and Formation-Sand Production in High Water Cut, Heavy-Oil Wells: A Field Study from Argentina

2009 ◽  
Author(s):  
Daniel Daparo ◽  
Luis Soliz ◽  
Eduardo Roberto Perez ◽  
Carlos Iver Vidal Saravia ◽  
Philip Duke Nguyen ◽  
...  
Keyword(s):  
Field Study ◽  
Heavy Oil ◽  
High Water ◽  
Oil Wells ◽  
Sand Production ◽  
High Water Cut ◽  
Water Cut

Water Control in High-Water-Cut Oil Wells using Relative Permeability Modifiers: A Saudi Lab Study

2017 ◽  
Author(s):  
Ibrahim Al-Hulail ◽  
Muzzammil Shakeel ◽  
Ahmed Binghanim ◽  
Mohamed Zeghouani ◽  
Raed Rahal ◽  
...  
Keyword(s):  
Relative Permeability ◽  
High Water ◽  
Oil Wells ◽  
Water Control ◽  
High Water Cut ◽  
Water Cut

scholarly journals Comments on “Is the Faroe Bank Channel Overflow Hydraulically Controlled?”

2009 ◽  
Vol 39 (6) ◽  
pp. 1534-1538 ◽  
Author(s):  
Linda Enmar ◽  
Karin Borenäs ◽  
Iréne Lake ◽  
Peter Lundberg
Keyword(s):  
Froude Number ◽  
Water Transport ◽  
Cross Section ◽  
Deep Water ◽  
Flow Analysis ◽  
Critical Flow ◽  
Hydraulic Theory

Abstract In a recent paper Girton et al., due to what appears to be a misunderstanding, stated that a critical-flow analysis of the deep-water transport through the Faroe Bank Channel had been undertaken by Lake et al. on the basis of rotating hydraulic theory for a channel of parabolic cross section. In fact, this quoted investigation dealt with a rectangular passage. In the present comment it is demonstrated how the use of parabolic bathymetry leads to significant improvements of the Froude number results.

scholarly journals Comparison Between Homogenous and Heterogeneous Reservoirs: A Parametric Study of Water Coning Phenomena

2021 ◽  
Vol 5 (1) ◽  
pp. 119-131
Author(s):  
Frzan F. Ali ◽  
Maha R. Hamoudi ◽  
Akram H. Abdul Wahab
Keyword(s):  
Production Rate ◽  
Oil Production ◽  
Water Production ◽  
Effective Parameters ◽  
Radial Cross Section ◽  
Heterogeneous Reservoirs ◽  
Water Breakthrough ◽  
Water Coning ◽  
Water Cut ◽  
Reservoir Simulator

Water coning is the biggest production problem mechanism in Middle East oil fields, especially in the Kurdistan Region of Iraq. When water production starts to increase, the costs of operations increase. Water production from the coning phenomena results in a reduction in recovery factor from the reservoir. Understanding the key factors impacting this problem can lead to the implementation of efficient methods to prevent and mitigate water coning. The rate of success of any method relies mainly on the ability to identify the mechanism causing the water coning. This is because several reservoir parameters can affect water coning in both homogenous and heterogeneous reservoirs. The objective of this research is to identify the parameters contributing to water coning in both homogenous and heterogeneous reservoirs. A simulation model was created to demonstrate water coning in a single- vertical well in a radial cross-section model in a commercial reservoir simulator. The sensitivity analysis was conducted on a variety of properties separately for both homogenous and heterogeneous reservoirs. The results were categorized by time to water breakthrough, oil production rate and water oil ratio. The results of the simulation work led to a number of conclusions. Firstly, production rate, perforation interval thickness and perforation depth are the most effective parameters on water coning. Secondly, time of water breakthrough is not an adequate indicator on the economic performance of the well, as the water cut is also important. Thirdly, natural fractures have significant contribution on water coning, which leads to less oil production at the end of production time when compared to a conventional reservoir with similar properties.

Data-driven technique for analyzing the injector efficiency in a waterflooding operation

SIMULATION ◽  
2020 ◽  
Vol 96 (8) ◽  
pp. 701-710
Author(s):  
Ali Shabani ◽  
Mahdiyeh Sadat Moosavi ◽  
Davood Zivar ◽  
Hamid Reza Jahangiri
Keyword(s):  
Early Time ◽  
Oil Reservoirs ◽  
Data Driven ◽  
Production Data ◽  
Production Rates ◽  
Flow Paths ◽  
Water Breakthrough ◽  
Economical Evaluation ◽  
Production Wells ◽  
Underground Flow

Waterflooding is considered as one of the most common methods for improving the ultimate recovery of oil reservoirs. The efficiency of a waterflooding operation strongly depends on the determination and quantification of the relative connections between the injection and production wells. Injection and production rates are the most accessible data and they can provide useful information about the interwell connections. Recently, several data-driven approaches, such as the capacitance resistance model (CRM), have been presented based on available reservoir data. The CRM is a valuable analytical model for estimating the production rates and interwell connections through optimization of the production data. In this study, a CRM is used in order to estimate the production rate and evaluate the underground flow paths for both synthetic and real cases. A new concept called Value of Injection (VoI) is developed for the injectors to analyze their performance in the early time of the waterflooding prior to the significant water breakthrough. The calculated VoI is directly used for economical evaluation of the injectors. The results of this study show that a strong underground connection between an injector–producer pair does not always result in higher efficiency of the injector.

scholarly journals Water cut/salt content forecasting in oil wells using a novel data-driven approach

2019 ◽  
Vol 74 ◽  
pp. 68
Author(s):  
Rouhollah Ahmadi ◽  
Jamal Shahrabi ◽  
Babak Aminshahidy
Keyword(s):  
Classification Tree ◽  
Salt Content ◽  
Oil Wells ◽  
Data Driven ◽  
Var Model ◽  
Support Vector ◽  
Water Production ◽  
Linear Discriminant ◽  
Data Driven Approach ◽  
Water Cut

Water cut is an important parameter in reservoir management and surveillance. Unlike traditional approaches, including numerical simulation and analytical techniques, which were developed for predicting water production in oil wells based on some assumptions and limitations, a new data-driven approach is proposed for forecasting water cut in two different types of oil wells in this article. First, a classification approach is presented for water cut prediction in sweet oil wells with discontinuous salt production patterns. Different classification algorithms including Support Vector Machine (SVM), Classification Tree (CT), Random Forest (RF), Multi-Layer Perceptron (MLP), Linear Discriminant Analysis (LDA) and Naïve Bayes (NB) are investigated in this regard. According to the results of a case study on a real Iranian sweet oil well, RF, CT, MLP and SVM can provide the best performance measures, respectively. Next, a Vector Autoregressive (VAR) model is proposed for forecasting water cut in salty oil wells with continuous water production during the life of the well. The proposed VAR model is verified using data of two real salty oil wells. The results confirm that the well-tuned proposed VAR model could provide reliable and acceptable results with very good accuracy in forecasting water production for the near future days.

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