Innovative Multiple-Zones Injector Completion Design in Unconsolidated Sand. A New Deployment Challenge in Highly Deviated Well in the Gulf of Thailand

2021 ◽  
Author(s):  
Thanudcha Khunmek ◽  
Keith Parrott ◽  
Ahamad Faidzal Bin Rosli
Keyword(s):  
Water Injection ◽  
Cost Effective ◽  
Injection Well ◽  
Gulf Of Thailand ◽  
Integrity Test ◽  
Drilling Rig ◽  
Sand Control ◽  
Injection Zone ◽  
The Gulf Of Thailand ◽  
Deviated Wells

Abstract The completion of a highly deviated well involves overcoming significant deployment challenges during the drilling operations that require precise and effective conveyance and intervention. The conventional slickline intervention is unsuitable for wells with more than 60° deviation. The operator has sought to implement efficient, reliable and cost-effective deployment methods in delivering injector well. Thus, the operator decided on the e-line tubing tractor conveyed with e-line key and an e-line stroking tool. A tubing tractor and mechanical key and stroker were used to convey the wireline key in highly deviated wells. The key and stroker tools are latched into the sliding side doors (SSDs). They will activate open or close SSDs by down-strokes or up-strokes. In particular, the SSDs are closed when it is required to pressure up the tubing to set the packers. After the packers are set, an integrity test is conducted to confirm zonal isolation. Finally, the SSD is shifted open by the tubing tractor and a low rate injection test is performed to confirm the status of the SSD before handover the well. The operation had successfully installed multiple zones injection completions (MZC) in a highly deviated well and complemented the new completion design for the sand control in water injection well. The e-line tubing tractor and well key/stroker tools have met all operational and budgetary expectations. The traditional intervention methods in highly deviated wells, such as coil tubing, can be costly and potentially infeasible due to a footprint constraint on the drilling rig. The completion was successfully installed without any HSSE issues and the lesson learnt was recorded for future interventions when a change of injection zones is required. For a water injector completion design, equipment was selected based on reservoir requirements i.e. sand control, injection rates and pressure, etc. The goal was to prevent sand from flowing into the tubing when water injection is temporarily paused. To address this concern, the team designed and implemented a cost- effective Autonomous Inflow Control Device (AICD) with bypass valves equipped with SSDs for injection zone selectivity. This first well has been on injection for more than two years with no sand observed in the tubing or declines in the injection rate. The e-line tubing tractor and well key/stroker tools enabled the success of this operations and should be an option for completions in highly deviated wells. Additionally, this is the first time an AICD with bypass valves has been installed for a water injection well in the Gulf of Thailand. The success achieved with this operation in the Nong Yao field provides operators with a new solution for dealing with the water injection in the unconsolidated reservoirs.

First Campos Basin Raw-Water-Injection Well: Sand Control and Stimulation

2010 ◽  
Author(s):  
Carlos Alberto Pedroso ◽  
Nilson Jose Denadai ◽  
Eduardo Lopes Duarte
Keyword(s):  
Water Injection ◽  
Injection Well ◽  
Raw Water ◽  
Campos Basin ◽  
Sand Control

Enabling Extended Reach Wells with the Aid of an Ultra-High Speed Rotational Reamer Shoe

2021 ◽  
Author(s):  
Manchukarn Naknaka ◽  
Chimere Nkwocha ◽  
Pattarapong Prasongtham ◽  
Tossapol Tongkum ◽  
Trinh Dinh Phu ◽  
...  
Keyword(s):  
High Speed ◽  
Drilling Fluid ◽  
Gulf Of Thailand ◽  
Integrity Test ◽  
Lost Circulation ◽  
Ultra High Speed ◽  
Open Hole ◽  
The Gulf Of Thailand ◽  
Difficulty Index ◽  
Extended Reach Drilling

Abstract Well X is an infill horizontal well designed for the Gulf of Thailand. It is challenging due to the following factors - A long 8 ½ inch open hole section, An extended reach section at horizontal or near horizontal, the presence of loss circulation zones, an Extended Reach Drilling (ERD) ratio of 2.725 and a Drilling Difficulty Index (DDI) of 6.762. The key challenge was to successfully deploy the 7 inch casing across 12,350 ftMD of open hole, with potential loss circulation zones. In spite of these difficulties, the 7 inch casing was successfully landed with the use of an Ultra-High Speed Rotational Reamer Shoe. Historically, losses of circulation have posed significant challenges to well delivery in the Gulf of Thailand wells. In Well X, this is further complicated by a long open-hole section with a step-out of over 10,000 ftMD. It was determined that the successful deployment of the 7 inch casing would require some degree of agitation at the nose, and such a device must be tolerant to the Lost Circulation Materials (LCM) type and the composition of the drilling fluid and the cement. An ultra-high speed rotational reamer shoe was specially configured to meet the LCM requirements in the displaced fluid, for use in deploying the casing. While deploying the 7 inch casing, losses of up to 20 bbls/hr occurred from 7,043 ftMD while running at 15 joints/hr. A loss circulation recipe comprising of 60 bbls of 30 ppb Tiger LCM was mixed and successfully displaced through the customized ultra-high speed reamer shoe to cure losses. The casing was washed down from 10,569 to 11,610 ftMD, filling casing each stand. The 7 inch casing was successfully landed at the target depth of 12,353 feet and subsequently cemented. Drill out operations took 1.5 hours to complete. A formation integrity test (FIT) showed good shoe strength which was later confirmed by the cement evaluation logs. The comprehensive Ultra-High Speed Reamer Shoe was configured with a minimum restriction of 15mm, which is 5 times the diameter of the maximum particle size in the LCM of 3 mm. The tool was designed to tolerate the prescribed loss circulation materials, making it possible to cure the losses while running the casing string. The innovative Ultra-High Speed Reamer Shoe has demonstrated its usefulness by providing a higher probability for successfully deploying the 7 inch production casing over the extended reach section of Well X. The application of this technology can mitigate against non-productive time such as wiper trips or excessive washing down or casing rotation. It has proven to be a reliable technology that can be used in the industry in challenging well designs.

Autonomously Controlling the Conformance of Injection-Well Fluids

2021 ◽  
Vol 73 (06) ◽  
pp. 38-40
Author(s):  
Mojtaba Moradi
Keyword(s):  
Flow Control ◽  
Oil Recovery ◽  
Water Injection ◽  
Injection Well ◽  
Reservoir Pressure ◽  
Injection Wells ◽  
Control Valves ◽  
Sand Control ◽  
Control Devices ◽  
Fracture Growth

As production declines over time, the injection of fluids is required to enhance oil recovery and/or maintain the reservoir pressure. Whether applied at field startup or as a secondary recovery technique, waterflooding can boost oil recovery from less than 30% to 30–50%. The common problems associated with waterflooding include loss of injectivity, premature injector failure, and injection conformance. This can also lead to issues around insufficient voidage replacement, which can result in lower reservoir pressure and the production of fluid with a higher gas/oil ratio. In total field recovery, this ultimately means lower production and oil left untapped in the well. To remediate the issue of conformance, costly and often complex interventions and redrills were traditionally used to restore water-injection capability. Also, passive outflow-control devices have been used successfully to somewhat improve the fluid conformance from injection wells. However, they may fail in reservoirs with complex/dynamic properties including propagating/dilating fractures. Advanced Wells in Injection Wells There are a number of considerations when planning a water-injection completion, particularly around both the rock and fluid properties, as well as the credible risks that could occur, namely: - Uneven displacement of hydrocarbon - Fracture growth short-circuiting injectant-proximal wells - Fracture growth breaching caprock/basement seal - Crossflow, plugging, and solids fill Advanced completion options include deploying passive flow-control devices. For example, inflow-control devices (ICDs) are unable to react to dynamic changes in reservoir/well properties. This often requires production-logging-tool (PLT) logs, distributed temperature sensors, and/or tracers to be run and, if available, to apply the sleeve option. Alternatively, active (intelligent) completions, such as inflow-control valves, can be used, but they tend to be expensive and complicated and are limited to the number of zones. This technique also requires frequent analysis of data from the well to perform such actions. Tendeka, a global specialist in advanced completions, production solutions, and sand control, has developed FloFuse, a new and exclusively autonomous rate-limiting outflow-control device (AOCD) (Fig. 1). Using the analogy and inspiration of a home fuse box, which contains many individual fuses to control various parts of a building, the AOCD can control the excessive rate that passes through a specific section of a well, causing tripping once the threshold is reached. By almost shutting, i.e., significantly choking, the injection fluid into the fractures crossing the well, the AOCD autonomously prevents growth and excessive fluid injection into the thief/fracture zones and maintains a balanced or prescribed injection distribution. Like other flow-control valves, this device should be installed in several compartments in the injection well. Initially, devices operate as normal passive outflow control, but if the injected flow rate through the valve exceeds a designed limit, the device will automatically shut off. This allows the denied fluid to that specific compartment to be distributed among the neighboring compartments.

New Phase of Formation Evaluation in the Gulf of Thailand

2011 ◽  
Author(s):  
Tanabordee Duangprasert ◽  
Saifon Daungkaew ◽  
Ronarong Paramatikul ◽  
Regis Vincent
Keyword(s):  
Gulf Of Thailand ◽  
Formation Evaluation ◽  
The Gulf Of Thailand ◽  
New Phase

Sand Free Production Success Through Proven Technology Enabler from An Untapped Heterogeneous Reservoir Zone Utilizing Gravel Pack Replacement Methodology

2020 ◽  
Author(s):  
Y. Anggoro
Keyword(s):  
Oil And Gas ◽  
Erosion Resistance ◽  
Cost Effective ◽  
High Rate ◽  
Screen Design ◽  
Sand Control ◽  
Rules Of Thumb ◽  
Production Success ◽  
Control Technologies ◽  
Gravel Pack

The Belida field is an offshore field located in Block B of Indonesia’s South Natuna Sea. This field was discovered in 1989. Both oil and gas bearing reservoirs are present in the Belida field in the Miocene Arang, Udang and Intra Barat Formations. Within the middle Arang Formation, there are three gas pay zones informally referred to as Beta, Gamma and Delta. These sand zones are thin pay zones which need to be carefully planned and economically exploited. Due to the nature of the reservoir, sand production is a challenge and requires downhole sand control. A key challenge for sand control equipment in this application is erosion resistance without inhibiting productivity as high gas rates and associated high flow velocity is expected from the zones, which is known to have caused sand control failure. To help achieve a cost-effective and easily planned deployment solution to produce hydrocarbons, a rigless deployment is the preferred method to deploy downhole sand control. PSD analysis from the reservoir zone suggested from ‘Industry Rules of Thumb’ a conventional gravel pack deployment as a means of downhole sand control. However, based on review of newer globally proven sand control technologies since adoption of these ‘Industry Rules of Thumb’, a cost-effective solution could be considered and implemented utilizing Ceramic Sand Screen technology. This paper will discuss the successful application at Block B, Natuna Sea using Ceramic Sand Screens as a rigless intervention solution addressing the erosion / hot spotting challenges in these high rate production zones. The erosion resistance of the Ceramic Sand Screen design allows a deployment methodology directly adjacent to the perforated interval to resist against premature loss of sand control. The robust ceramic screen design gave the flexibility required to develop a cost-effective lower completion deployment methodology both from a challenging make up in the well due to a restrictive lubricator length to the tractor conveyancing in the well to land out at the desired set depth covering the producing zone. The paper will overview the success of multi-service and product supply co-operation adopting technology enablers to challenge ‘Industry Rules of Thumb’ replaced by rigless reasoning as a standard well intervention downhole sand control solution where Medco E&P Natuna Ltd. (Medco E&P) faces sand control challenges in their high deviation, sidetracked well stock. The paper draws final attention to the hydrocarbon performance gain resulting due to the ability for choke free production to allow drawing down the well at higher rates than initially expected from this zone.

Sign in / Sign up

Export Citation Format

Share Document