Innovative Washpipe Free Circulating ICD Delivers Reduced Well Construction Costs

2021 ◽  
Author(s):  
Zhihua Wang ◽  
Daniel Newton ◽  
Aqib Qureshi ◽  
Yoshito Uchiyama ◽  
Georgina Corona ◽  
...  
Keyword(s):  
United Arab Emirates ◽  
Drilling Fluid ◽  
Aqueous Fluid ◽  
Control Device ◽  
Lessons Learned ◽  
Innovative Technology ◽  
Well Performance ◽  
Construction Costs ◽  
Inflow Control Device ◽  
Testing Field

Abstract This Extended Reach Drilling (ERD) field re-development of a giant offshore field in the United Arab Emirates (UAE) requires in most cases extremely long laterals to reach the defined reservoir targets. However, certain areas of the field show permeability and / or pressure variations along the horizontal laterals. This heterogeneity requires an inflow control device (ICD) lower completion liner to deliver the required well performance that will adequately produce and sweep the reservoir. The ICD lower completion along with the extremely long laterals means significant time is spent switching the well from reservoir drilling fluid (RDF) non-aqueous fluid (NAF) to an aqueous completion brine. To reduce the amount of rig time spent on the displacement portion of the completion phase, an innovative technology was developed to enable the ICDs to be run in hole in a closed position and enable circulating through the end of the liner. The technology uses a dissolvable material, which is installed in the ICD to temporarily plug it. The dissolvable material is inert to the RDF NAF while the ICDs are run into hole, and then dissolves in brine after the well is displaced from RDF NAF to completion brine, changing the ICDs from closed to an open position. The ability to circulate through the end of the liner, with the support of the plugged ICDs, when the lower completion is deployed and at total depth (TD), enables switching the well from RDF NAF drilling fluid to an aqueous completion brine without the associated rig time of the original displacement method. The technique eliminates the use of a dedicated inner displacement string and allows for the displacement to be performed with the liner running string, saving 4-5 days per well. An added bonus is that the unique design allowed for this feature to be retrofitted to existing standard ICDs providing improved inventory control. In this paper the authors will demonstrate the technology and system developed to perform this operation, as well as the qualification testing, field installations, and lessons learned that were required to take this solution from concept to successful performance improvement initiative.

The Development of a Pressure Actuated Isolation Nozzle Assembly and its Application as Flow Control Device in Extended Reach Water-Alternating-Gas Pilot Wells

2021 ◽  
Author(s):  
Zhihua Wang ◽  
Aqib Qureshi ◽  
Tarik A Abdelfattah ◽  
Joshua R Snitkoff
Keyword(s):  
Flow Control ◽  
Drilling Fluid ◽  
Applied Pressure ◽  
Control Device ◽  
Lessons Learned ◽  
Production Performance ◽  
Dissolution Time ◽  
Enhanced Production ◽  
Water Alternating Gas ◽  
Flow Control Device

Abstract The re-development of a giant offshore field in the United Arab Emirates (UAE) consists predominantly of four artificial islands requiring in most cases extremely long horizontal laterals to reach the reservoir targets. Earlier SPE technical papers (1,2) have introduced the development, testing, qualification, and deployment of the plugged liner technology using the dissolvable plugged nozzles (DPNs). The use of DPN plugged liner technology has resulted in CAPEX savings and enhanced production performance. The benefits of DPN technology are its simplicity along with its cost effectiveness. However, the dissolvable material has some limitations, such as pressure rating and dissolution time, which are fluid chemistry dependent. To overcome these limits, a new Pressure Actuated Isolation Nozzle Assembly (PAINA) was developed as an alternative to the plugged liner tool for applications where a higher pressure rating is required, as well as on demand opening. Furthermore, the new PAINA also functions as a flow control device during injection and production, enhancing acid jetting effects during bullhead stimulation and reducing brine losses during liner installation. Liners with PAINAs can be run to TD similar to blank pipe: fluids can be circulated through the inside of the liner without the need for a wash pipe. Once on bottom, non-aqueous drilling fluid is displaced to brine without actuating the isolation mechanism. When the well is ready for production or injection, pressure is applied and the isolation mechanism is activated to establish communication between well and reservoir. These tools were successfully run as flow control devices in water-alternating-gas (WAG) pilot wells. The planning and execution of the initial application will be discussed, along with the tool development, qualification testing, and lessons learned. The key advantage of this technology is in extending plugged liner applications to cases where other pressure-operated tools are included as part of the liner lower completion. Pressure can be applied to the well multiple times without activating the isolation mechanism as long as the applied pressure is below the actuation pressure.

Successfully Installing ICD Screens and Hydraulic Packers without Washpipe Using Novel Check-Valve ICDS: Case Study Offshore Canada

2021 ◽  
Author(s):  
Ashutosh Dikshit ◽  
Amrendra Kumar ◽  
Bruce Froom
Keyword(s):  
Check Valve ◽  
Cost Effective ◽  
Control Device ◽  
Lessons Learned ◽  
Fluid Circulation ◽  
Strict Adherence ◽  
Porous Aluminum ◽  
Challenging Environment ◽  
Technical Details ◽  
Inflow Control Device

Abstract Objective was to complete two ~16,000 ft MD offshore, openhole, horizontal wells with inflow control device (ICD) screens and hydraulic packers in acost-effective and risk-reduced manner. A major goal for the lower completion was to eliminate running washpipe for fluid circulation and intervention stringfor hydraulic packer setting to reduce rig time, equipment costs and operation/safety risks. A cost effective check-valve inflow control device (CV-ICD) screen solution, as described herein, was used on these two wells to achieve both of these purpose. CV-ICD consists a nozzle with a 1) ceramic ball to seal against it's throat and 2) porous aluminum plate to retain the loose ball until injection pushes it against the throat. Extensive testing was performed under target conditions to ensure a 5,000psi differential pressure rating for setting open hole hydraulic packer. Strict adherence to technical details helped transform the relatively simple concept of a ball-type, CV-ICD into a robust and reliable technology. The results of the extensive laboratory testing, as discussed herein, demonstrated: 1) HTHP functionality of the CV-ICD before/after exposure to wellbore fluids, 2) removal of the aluminum "cage" only after the ball is no longer required, and 3) acceptable flow performance of the ICDs with/without the loose ball present. Strict manufacturing and onsite QAQC procedures proved indispensable for success, especially given the challenging environment offshore. Fluid circulation through the toe valve without washpipe was achieved while running the screen in wellbore. After reaching target depth (TD), the toe valve was closed there by allowing the string to be pressured up to set the hydraulic packers. The tubing pressure was successfully increased to ~5,000 psi against CV-ICDs to set the hydraulic packers. Overall, the completions were a success as discussed in more detail herein, along with valuable lessons learned. The case studies presented herein demonstrated costs and risks associated with using a washpipe to deploy ICD screens to TD can be significantly reduced with a novel yet cost-effective CV-ICD solution. The integration of check ball with an ICD, while simple in concept, provide siginifcant value if the strict adherence to technical details, rigorous testing and diligent quality control are followed.

Development and First Application of an Ultra-Low Density Non-Aqueous Reservoir Drilling Fluid in the United Arab Emirates: A Viable Technical Solution to Drill Maximum Reservoir Contact Wells Across Depleted Reservoirs

2021 ◽  
Author(s):  
Ramanujan Jeughale ◽  
Kerron Andrews ◽  
Salim Abdalla Al Ali ◽  
Takahiro Toki ◽  
Hisaya Tanaka ◽  
...  
Keyword(s):  
United Arab Emirates ◽  
Drilling Fluid ◽  
Surface Condition ◽  
Field Application ◽  
Lessons Learned ◽  
Technical Solution ◽  
Low Density ◽  
Reservoir Water ◽  
Laboratory Test Results ◽  
Organophilic Clay

Abstract Drilling and completion operations in depleted reservoirs, are challenging due to narrow margin between pore and fracture pressures. Therefore, Ultra-Low Density Reservoir Drilling Fluid (RDF) with optimum parameters is required to drill these wells safely. Design and effective field application of a sound engineered fluid solution to fulfill these operational demands are described. Ultra-Low Density RDF NAF with minimal fluid invasion characteristics was developed after extensive lab testing, to cover the fluid density from 7.2 – 8.0 ppg. The fluid properties were optimized based on reservoir requirements and challenging bottom-hole conditions. The design criteria benchmarks and field application details are presented. Fluids were stress tested for drill solids, reservoir water and density increase contamination. Multi-segment collaboration and teamwork were key during job planning and on-site job execution, to achieve operational success. For the first time in UAE, a major Offshore Operator successfully applied an Ultra-Low Density RDF-NAF, which provided remarkable stability and performance. The fluid was tested in the lab with polymeric viscosifier alone and in combination with organophilic clay. In order to gain rheology during the initial mixing, about 3.0 ppb of organophilic clay were introduced to system along with the polymeric viscosifier. Later, all the new fluid batches were built with polymeric additives alone to achieve target properties. A total of 10,250 ft of 8 ½" horizontal section was drilled to section TD with record ROP compared to previous wells in the same field, with no fluids related complications. With limited support from the solid control equipment, the team managed to keep the density ranging from 7.5 ppg to 7.8 ppg at surface condition, using premixed dilution. Bridging was monitored through actual testing on location and successfully maintained the target PSD values throughout the section by splitting the flow on three shaker screen size combination. Due to non-operation related issues, hole was kept static for 20 days. After such long static time, 8 ½" drilling BHA was run to bottom smoothly precautionary breaking circulation every 5 stands. Finally, after successful logging operation, 6 5/8" LEL liner was set to TD and the well completed as planned. Success of this field application indicates that an Ultra-Low density fluid can be designed, run successfully and deliver exemplary performance. Lessons learned are compared with conceptual design for future optimization. Laboratory test results are presented, which formed the basis of a seamless planned field application.

A Novel Inflow Control Device Design Philosophy of Optimizing Horizontal Well Performance

2016 ◽  
Author(s):  
Mengjing Cao ◽  
Xiaodong Wu ◽  
Yongsheng An ◽  
Guoqing Han ◽  
Ruihe Wang ◽  
...  
Keyword(s):  
Horizontal Well ◽  
Control Device ◽  
Device Design ◽  
Well Performance ◽  
Design Philosophy ◽  
Inflow Control Device

The Autonomous Inflow Control Valve Design and Evaluation Criteria Along with Well Performance Review for Multiple Installations Across the Globe

2021 ◽  
Author(s):  
Tejas Kalyani ◽  
Haavard Aakre ◽  
Vidar Mathiesen
Keyword(s):  
Evaluation Criteria ◽  
Control Valve ◽  
Control Device ◽  
Well Performance ◽  
Flow Loop ◽  
Wide Range ◽  
Fluid Properties ◽  
Inflow Control Device ◽  
Water Cut ◽  
Flow Element

Abstract Many wells across the globe have been installed with Inflow Control Device (ICD) technology to balance the production across the production interval, addressing some of the challenges associated with horizontal and deviated wells. Nevertheless, ICDs have limitations with restricting unwanted fluids upon breakthrough. Autonomous Inflow Control Valve (AICV) technology functions similar to an ICD initially (i.e., balancing flux across the length of horizontal wells, effectively delaying breakthrough) but provides the additional benefit of shutting off the flow of unwanted fluids upon breakthrough. This paper will present comprehensive AICV completion design workflow along with multiple case histories highlighting the reservoir management benefits of the AICV technology in mitigating un-wanted inflow of water and gas and delivering improved oil production and recovery. Like other AICDs (Autonomous Inflow Control Device), AICV can differentiate the fluid flowing through it via fluid properties such as viscosity and density at reservoir conditions. However, AICV's performance is much more effective due to its advanced design which provides further benefits using both Hagen-Poiseuille's and Bernoulli's principles. AICV technology is based on the difference in the pressure drop in a laminar flow element (LFE) compared to a turbulent flow element (TFE) and has a capability to shut-off the main flow autonomously when an unwanted fluid such as water or gas breakthrough occurs. Thus, reduces well water cut (WC) and/or gas-oil ratio (GOR) significantly. Rigorous single-phase and multiphase flow-loop tests have been conducted covering a wide range of fluid properties to characterize the AICVs flow performance. Extensive plugging testing and accelerated erosion tests have also been conducted. This paper presents some of these flow performance analysis and testing results. Furthermore, the paper will also discuss in detail a reservoir-centric AICV completion modelling and design workflow. Finally, this papers also discuss in detail AICV well performance installed in a light oil as well as in heavy oil reservoirs and how operators achieved higher OPEX saving as well as higher ultimate recovery (UR) from the wells due to prolonged as well as significant reduction in water cut and/or lower GOR. The AICV design methodology and performance evaluation analysis is presented through several case studies. The analysis takes into account the whole cycle: from flow loop testing to characterization, reservoir modelling, optimized AICV completion design and post-installation well performance to evaluate the AICV technology benefits.

Sign in / Sign up

Export Citation Format

Share Document