Expanding the Envelope of Coiled-Tubing (CT) Reach for Stimulation of Ultradeep Openhole Horizontal Wells

2010 ◽  
Author(s):  
Mubarak Audah Al-Dhufairi ◽  
Saleh Al-Ghamdi ◽  
Jose Vidal Noya ◽  
Khaled Al-Aradi ◽  
Samer Al-Sarakbi ◽  
...  
Keyword(s):  
Horizontal Wells ◽  
Coiled Tubing ◽  
Stimulation Of

Case Study- Real Time Downhole Telemetry CCL and Tension Compression, a Differentiator for Successful Manipulation of ICD's in Horizontal Wells

2021 ◽  
Author(s):  
Usman Ahmed ◽  
Zhiheng Zhang ◽  
Ruben Ortega Alfonzo
Keyword(s):  
Saudi Arabia ◽  
Real Time ◽  
Oil Recovery ◽  
Horizontal Wells ◽  
Differential Pressure ◽  
Successful Operation ◽  
Coiled Tubing ◽  
Electric Line ◽  
Wide Range ◽  
Ict System

Abstract Horizontal well completions are often equipped with Inflow Control Devices (ICDs) to optimize flow rates across the completion for the whole length of the interval and to increase the oil recovery. The ICD technology has become useful method of optimizing production from horizontal wells in a wide range of applications. It has proved to be beneficial in horizontal water injectors and steam assisted gravity drainage wells. Traditionally the challenges related to early gas or water breakthrough were dealt with complex and costly workover/intervention operations. ICD manipulation used to be done with down-hole tractor conveyed using an electric line (e-line) cable or by utilization of a conventional coiled tubing (CT) string. Wellbore profile, high doglegs, tubular ID, drag and buoyancy forces added limitations to the e-line interventions even with the use of tractor. Utilization of conventional CT string supplement the uncertainties during shifting operations by not having the assurance of accurate depth and forces applied downhole. A field in Saudi Arabia is completed with open-hole packer with ICD completion system. The excessive production from the wells resulted in increase of water cut, hence ICD's shifting was required. As operations become more complex due to fact that there was no mean to assure that ICD is shifted as needed, it was imperative to find ways to maximize both assurance and quality performance. In this particular case, several ICD manipulating jobs were conducted in the horizontal wells. A 2-7/8-in intelligent coiled tubing (ICT) system was used to optimize the well intervention performance by providing downhole real-time feedback. The indication for the correct ICD shifting was confirmed by Casing Collar Locator (CCL) and Tension & Compression signatures. This paper will present the ICT system consists of a customized bottom-hole assembly (BHA) that transmits Tension, compression, differential pressure, temperature and casing collar locator data instantaneously to the surface via a nonintrusive tube wire installed inside the coiled tubing. The main advantages of the ICT system in this operation were: monitoring the downhole force on the shifting tool while performing ICD manipulation, differential pressure, and accurately determining depth from the casing collar locator. Based on the known estimated optimum working ranges for ICD shifting and having access to real-time downhole data, the operator could decide that required force was transmitted to BHA. This bring about saving job time while finding sleeves, efficient open and close of ICD via applying required Weight on Bit (WOB) and even providing a mean to identify ICD that had debris accumulation. The experience acquired using this method in the successful operation in Saudi Arabia yielded recommendations for future similar operations.

Stimulation Of Horizontal Wells Using Diverted Acid Treatments

10.2118/93-20 ◽  
1993 ◽  
Author(s):  
Kelvin Williamson ◽  
Chad Randal ◽  
Joe Stadlwieser ◽  
Frank O'Neill
Keyword(s):  
Horizontal Wells ◽  
Stimulation Of ◽  
Acid Treatments

The Effect of Well Azimuth or Don't Let Your Landman Plan Your Well Path!

2015 ◽  
Author(s):  
Fen Yang ◽  
Larry K. Britt ◽  
Shari Dunn-Norman
Keyword(s):  
Horizontal Well ◽  
Oil And Gas ◽  
Horizontal Wells ◽  
Horizontal Stress ◽  
Well Performance ◽  
Gas Reservoirs ◽  
Principal Stresses ◽  
Lateral Direction ◽  
Well Completion ◽  
Stimulation Of

Abstract Since the late 1980's when Maersk published their work on multiple fracturing of horizontal wells in the Dan Field, the use of transverse multiple fractured horizontal wells has become the completion of choice and become the “industry standard” for unconventional and tight oil and tight gas reservoirs. Today approximately sixty percent of all wells drilled in the United States are drilled horizontally and nearly all of them are multiple fractured. Because a horizontal well adds additional cost and complexity to the drilling, completion, and stimulation of the well we need to fully understand anything that affects the cost and complexity. In other words, we need to understand the affects of the principal stresses, both direction and magnitude, on the drilling completion, and stimulation of these wells. However, little work has been done to address and understand the relationship between the principal stresses and the lateral direction. This paper has as its goal to fundamentally address the question, in what direction should I drill my lateral? Do I drill it in the direction of the maximum horizontal stress (longitudinal) or do I drill it in the direction of the minimum horizontal stress (transverse)? The answer to this question relates directly back to the title of this paper and please "Don't let your land man drive that decision." This paper focuses on the horizontal well's lateral direction (longitudinal or transverse fracture orientation) and how that direction influences productivity, reserves, and economics of horizontal wells. Optimization studies using a single phase fully three dimensional numeric simulator including convergent non-Darcy flow were used to highlight the importance of lateral direction as a function of reservoir permeability. These studies, conducted for both oil and gas, are used to identify the point on the permeability continuum where longitudinal wells outperform transverse wells. The simulations compare and contrast the transverse multiple fractured horizontal well to longitudinal wells based on the number of fractures and stages. Further, the effects of lateral length, fracture half-length, and fracture conductivity were investigated to see how these parameters affected the decision over lateral direction in both oil and gas reservoirs. Additionally, how does completion style affect the lateral direction? That is, how does an open hole completion compare to a cased hole completion and should the type of completion affect the decision on in what direction the lateral should be drilled? These simulation results will be used to discuss the various horizontal well completion and stimulation metrics (rate, recovery, and economics) and how the choice of metrics affects the choice of lateral direction. This paper will also show a series of field case studies to illustrate actual field comparisons in both oil and gas reservoirs of longitudinal versus transverse horizontal wells and tie these field examples and results to the numeric simulation study. This work benefits the petroleum industry by: Establishing well performance and economic based criteria as a function of permeability for drilling longitudinal or transverse horizontal wells,Integrating the reservoir objectives and geomechanic limitations into a horizontal well completion and stimulation strategy,Developing well performance and economic objectives for horizontal well direction (transverse versus longitudinal) and highlighting the incremental benefits of various completion and stimulation strategies.

An Alternative Tool for Production Logging in Horizontal Wells

2021 ◽  
Author(s):  
Nadir Husein ◽  
Jianhua Xu ◽  
Igor Novikov ◽  
Ruslan Gazizov ◽  
Anton Buyanov ◽  
...  
Keyword(s):  
Continuous Production ◽  
Analytical Data ◽  
Horizontal Wells ◽  
Optimal Length ◽  
Well Drilling ◽  
Actual Distribution ◽  
Well Completion ◽  
Coiled Tubing ◽  
Additional Equipment ◽  
Getting Lost

Abstract From year to year, well drilling is becoming more technologically advanced and more complex, therefore we observe the active development of drilling technologies, well completion and production intensification. It forms the trend towards the complex well geometry and growth of the length of horizontal sections and therefore an increase of the hydraulic fracturing stages at each well. It's obvious, that oil producing companies frequently don't have proved analytical data on the actual distribution of formation fluid in the inflow profiles for some reasons. Conventional logging methods in horizontal sections require coiled tubing (CT) or downhole tractors, and the well preparation such as drilling the ball seat causing technical difficulties, risks of downhole equipment getting lost or stuck in the well. Sometimes the length of horizontal sections is too long to use conventional logging methods due to their limitations. In this regard, efficient solution of objectives related to the production and development of fields with horizontal wells is complicated due to the shortage of instruments allowing to justify the horizontal well optimal length and the number of MultiFrac stages, difficulties in evaluating the reservoir management system efficiency, etc. A new method of tracer based production profiling technologies are increasingly applied in the global oil industry. This approach benefits through excluding well intervention operations for production logging, allows continuous production profiling operations without the necessity of well shut-in, and without involving additional equipment and personal to be located at wellsite.

First Multistage Hydraulic Fracturing in Russian Offshore: Integrated Approach to Completion and Stimulation of Apt Deposits of V.Filanovsky Field

2021 ◽  
Author(s):  
Mikhail Yurievich Golenkin ◽  
Denis Vladimirovich Eliseev ◽  
Alexander Anatolyevich Zemchikhin ◽  
Alexey Alexandrovich Borisenko ◽  
Akhmat Sakhadinovich Atabiyev ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Caspian Sea ◽  
Complex Type ◽  
The Caspian Sea ◽  
Multistage Hydraulic Fracturing ◽  
Coiled Tubing ◽  
Sand Control ◽  
Friction Reducing ◽  
First Time ◽  
Stimulation Of

Abstract The paper describes the results of the first multistage hydraulic fracturing operations in Russia on the Caspian Sea shelf in the gas condensate and oil deposits of the Aptian formation of V. Filanovsky field. In addition to the small productive formation depth, long horizontal sections with a complex trajectory and high collapse gradients due to large zenith angles when passing the Albian and Aptian deposits of poorly consolidated sandstones are an additional challenge for choosing a multistage hydraulic fracturing assembly. The above features require the use of modern sand control screens with enhanced frac sleeves. A design was developed which includes frac sleeves and sand control screens that can withstand multiple cycles of hydraulic impact during hydraulic fracturing, as well as many opening/closing cycles. A seawater-based frac fluid system was applied. The frac fleet was located on a pontoon, the coiled tubing – on a platform. For the first time in Russia, a 2-5/8 inch coiled tubing with a complex-type friction reducing system was used to switch coupling/sleeves in conditions of very long horizontal sections, complex trajectories, and high friction coefficients. The minimum distances between the screen's sliding sleeves and frac sleeves did not prevent from performing manipulations in complex environment. For well cleaning, the frac assemblies of reverse rotary-pulse and rotary-directional types were used. At the first stage of the project, the development of an optimal method of well completion was successfully implemented. Due to the close interaction of the operating company, service company, and science & engineering team of the operator, for the first time in Russia the design of downhole equipment with the use of advanced technologies of sand control screens, frac sleeves was presented. This solution has proved its effectiveness – the downhole equipment has retained its operational properties after a long period of well operation and further in the process of hydraulic fracturing. At the second stage of the project, 32 MSHF operations were performed at four wells. To reduce nonproductive time and operational risks, a satellite communication complex was additionally deployed on the pontoon to join the engineering centers of Astrakhan, Moscow, and Houston. After finishing the well development, the design indicators for formation fluid rates were achieved, which proved the effectiveness of the stimulation of the field's target objects – this opens great prospects for further development of low-permeability reservoirs at offshore sites in the Caspian Sea. The successful project implementation and the achievement of the design values of oil flow rates has expanded the possibilities of commercial operation of the low-permeable Aptian formation, complicated by the presence of a gas cap and underlying water. A solution was presented for working in extended horizontal well sections with 2-5/8 inch coiled tubing together with a complex-type mechanical friction reducing system. The economic effect was achieved when solving tasks of manipulating mechanical screen couplings and frac port sleeves without the involvement of downhole tractors. The use of new solutions in the completion assembly made it possible to eliminate additional sand ingress problems.

Three-Phase Flow Profile Determination of A Horizontal Well in Offshore by Tracer Technology

2021 ◽  
Author(s):  
Alexander Katashov ◽  
Igor Novikov ◽  
Evgeny Malyavko ◽  
Nadir Husein
Keyword(s):  
Oil And Gas ◽  
Horizontal Wells ◽  
Oil And Gas Industry ◽  
World Market ◽  
Dynamic Mode ◽  
Flow Profile ◽  
Offshore Platforms ◽  
Field Development ◽  
Coiled Tubing ◽  
Three Phase

Abstract Over the past few years, the oil and gas industry has faced a situation of high fluctuations in hydrocarbon prices on the world market. In addition, the trend for the depletion of traditional hydrocarbon reservoirs and the search for new effective solutions for the management and control of field development using horizontal and multilateral wells is still relevant. The most common method for horizontal wells testing is production logging tools (PLT) on coiled tubing (CT) or downhole tractor, which is associated with HSE risks and high cost, especially on offshore platforms, which limits the widespread use of this technology. The solution without such risks is the method of marker well monitoring, which allows obtaining information about the profile and composition of the inflow in a dynamic mode in horizontal wells without well intervention. There are several types of tracer (marker) carriers and today we will consider an approach to placing marker monitoring systems as part of a completion for three-phase oil, water and gas monitoring.

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