New Coiled-Tubing Cementing Techniques at Prudhoe Developed To Withstand Higher Differential Pressure

1993 ◽  
Vol 8 (04) ◽  
pp. 260-262
Author(s):  
R.E. Krause ◽  
D.C. Reem
Keyword(s):  
Differential Pressure ◽  
Coiled Tubing ◽  
Cementing Techniques

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.

Success Story of Single-Job Multiple Zones Chemical Sand Consolidation in Mahakam Delta

2020 ◽  
Author(s):  
S. Warsito
Keyword(s):  
Differential Pressure ◽  
Curing Time ◽  
Success Story ◽  
Additional Risk ◽  
Success Ratio ◽  
Coiled Tubing ◽  
Mahakam Delta ◽  
Resin Curing

Multiple zones chemical sand consolidation jobs are often avoided because of low success ratio. Strict operational and technical limitations must be respected to ensure the quality of the treatment. Conventional chemical sand consolidation operations performed in Delta Mahakam were done by using coiled tubing and packer to inject the resin into single reservoir. Multi-zone chemical sand consolidation poses additional risk of interfering with newly treated formation. Therefore, a temporary plug was installed in between the reservoirs which serve as temporary isolation to prevent the newly treated formation. The plug needs to withstand maximum differential pressure which would be exerted during the treatment. Other important factors include to test the limitations of resin curing time prior to proceed with the next treatment.

E-Line Powered Mechanical Tool Technologies Provide Efficient, Reduced Risk Solutions in Complex Intervention Operations

2021 ◽  
Author(s):  
Ghulam Murtaza Kalwar ◽  
Saad Hamid ◽  
Sharat Kishore ◽  
Abdulrahman A. Aljughayman ◽  
Nahr M. Abulhamayel ◽  
...  
Keyword(s):  
Real Time ◽  
Complex Intervention ◽  
Differential Pressure ◽  
Linear Actuator ◽  
Operating Parameters ◽  
Precise Control ◽  
Coiled Tubing ◽  
Axial Forces ◽  
Ceramic Disk ◽  
Mechanical Intervention

Abstract Latest developments in drilling and wellbore completion technologies lead to even more complex intervention conditions. Conventional techniques using slickline or coiled tubing are ill-suited for many of these conditions due to operational complexity, effectiveness, or efficiency. Powered mechanical intervention with e-line alleviates some of these limitations and opens lower risk intervention applications. This paper details two applications: a fishing operation that could not be performed with slickline or coiled tubing and a completion disk rupturing operation where the operator saved 1.5 days. Powered mechanical intervention is a combination of complementary technologies that enable "intelligently controlled intervention operations." Downhole tractors enable access into complex well trajectories. Surface-controlled, powered anchors coupled with a linear actuator can generate very high axial forces with precise and real-time downhole measurements of forces and displacement. Operating parameters can be monitored in real time to prevent damage to damaged completion components. Uncontrolled tool movement due to high differential pressures is prevented. Such precise control of downhole forces and movements enables complex intervention operations previously done with coiled tubing or a full workover. The first application example details a fishing operation. A retrievable plug along with its setting tool was stuck in the production tubing after prematurely setting. Multiple fishing attempts with heavy-duty slickline jars were unsuccessful. Coiled tubing was not deployed as its lack of force precision could have generated excessive downhole force and sheared the fish. An e-line-conveyed linear actuator tool was used to latch onto the fish with the help of an overshot and was released from the retrievable plugs by application of optimal, highly controlled, linear force to minimize damage. The second case involved rupturing a ceramic disk installed in completion. High differential pressure across the disk restricted the use of slickline which could have been damaged due to the high expected differential pressure. The alternative with coiled tubing milling requires a larger personnel and equipment footprint in addition to the associated HSE exposure and lack of efficiency. An innovative technique using the e-line linear actuator and a pointed chisel was devised and deployed. Real-time feedback from the tool sensors gave confirmation of the rupturing of various components of the ceramic disk, and the anchors eliminated any tool movement during pressure equalization. The operation was completed in 12 hours, resulting in time savings of almost 36 hours. An e-line intervention is a low risk, effective, and efficient solution while having an accurate depth and positioning, coupled with controlled downhole operations. With precise control of operating parameters, operations which were previously possible with coiled tubing or workover can be done on e-line more efficiently.

Successful Intervention of Coiled Tubing Rugged Tool with Real-Time Telemetry System in Saudi Arabia First Multistage Fracturing Completion with Sand Control System

2021 ◽  
Author(s):  
Ahmed N. Alduaij ◽  
Zakareya Al-Bensaad ◽  
Danish Ahmed ◽  
Mohd Nazri Bin Md Noor ◽  
Nabil Batita ◽  
...  
Keyword(s):  
Real Time ◽  
Differential Pressure ◽  
Telemetry System ◽  
Sand Production ◽  
Coiled Tubing ◽  
Sand Control ◽  
Tension And Compression ◽  
Downhole Tool ◽  
Closed Position ◽  
Open Position

Abstract An openhole multistage completion required selective fracture stimulation, flow control, and sand control in each zone. An openhole multistage completion was designed by combining a production sleeve integrated with sand screens and inflow control devices and a fracture sleeve with high open flow port. The system was designed to use a ball drop to isolate the bottom intervals while fracturing upper intervals. After fracture stimulation, the fracture seat/ball needed to be milled. The production sleeve were designed to be shifted to the open position and the fracturing sleeve to the closed position through mechanical shifting tool to put the well on production. The fracturing sleeve and the production sleeve were located close to each other and a successful shifting operation needed an appropriate shifting tool, with a real-time downhole telemetry system that met the temperature limitations while providing accurate depth control, differential pressure readings, and axial force (tension and compression) measurements. Hydraulic-pressure-activated shifting tools were used to manipulate the sleeves. A coiled tubing (CT) rugged downhole tool with real-time telemetry was used to run the shifting tools. Yard tests were conducted to identify the optimum rates and pressures to actuate the hydraulically activated shifting tools and study their behavior. The expansion of the fracturing sleeve shifting tool keys initiated at 1.6 bbl/min (400 psi) and the keys were fully expanded at 1.8 bbl/min (600 psi), whereas the expansion of production sleeve shifting tool keys initiated at 0.3 bbl/min (700 psi), and the keys were fully expanded at 0.4 bbl/min (900 psi). During the design and planning of the shifting operation, simulations were conducted, and surface and downhole tools were selected carefully to ensure the CT could provide enough downhole upward force (5,000 to 6,000 lbf) to close the fracture ports and 2,000 to 4,000 lbf to open production sleeves. Following the fracturing operation, the first CT run aimed to mill fracture seats/balls to clear the path for the subsequent shifting operation. In the second CT run, all the fracturing sleeves were shifted to the closed position while production sleeves were shifted to the open position. The CT rugged downhole tool proved critical for depth correlation and accurate placement of the shifting tools. The real-time downhole acquisition of differential pressure across the toolstring also allowed operating the shifting tools under optimum conditions, while downhole force readings of tension and compression confirmed the shifting of completion accessories. Two fracturing sleeves were shifted to the closed position at 2.4 bbl/min and 700-psi downhole differential pressure, with the downhole weights of 700 lb and 1,000 lbf. Three production sleeves were shifted to open position at 0.6 bbl/min and 1,200-psi downhole differential pressure, and the maximum surface and downhole weights recorded were 73,000 lb and 19,200 lb, respectively. That operation led to sand-free production and confirmed the success of the first multistage completion enabling fracturing operation and controlling sand production in Saudi Arabia. This study describes the use of real-time downhole measurements and their significance when surface parameters do not give clear indication of shifting. It also features the first-time use of two hydraulically activated shifting tools operated during the shifting operation in Saudi Arabia's first multistage completion enabling fracturing operation and controlling flow/sand production.

Improved Coiled-Tubing Squeeze-Cementing Techniques at Prudhoe Bay

1991 ◽  
Vol 43 (04) ◽  
pp. 455-459 ◽  
Author(s):  
P. Rosemary Hornbrook ◽  
Clifton M. Mason
Keyword(s):  
Coiled Tubing ◽  
Prudhoe Bay ◽  
Cementing Techniques

State-of-the-Art Coiled Tubing Technology at Prudhoe Bay, Alaska

2007 ◽  
Author(s):  
Jennifer Yvonne Julian ◽  
Kirk Charles Forcade ◽  
Taylor L. West ◽  
Kevin yeager ◽  
Robert Lee Mielke ◽  
...  
Keyword(s):  
State Of The Art ◽  
Coiled Tubing ◽  
Prudhoe Bay
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