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Abstract Wellbore obstructions are a common dilemma and typically must be removed as they can severely restrict a well’s production capability and have proven to be very costly. For instance, scale formation will eventually result in lower yields and well failure, while a fish left in a well can hamper future wellbore operations. The thru-tubing well intervention impact hammer was designed to dislodge fish or scale from a wellbore, by delivering an upward or downward impact force. The tool is activated by flow, in combination with compressive or tensile force, depending on the required impact. In operations that require bi-directional forces, both the single-acting up (SAU) and single- acting down (SAD) can be used concurrently on the same bottom-hole assembly (BHA). This paper describes the performance of "fluid activated impact hammers" for fishing operations. Case histories of recent field results are also discussed which illustrate the efficient removal of wellbore obstructions in deviated wells. This enables the well to be put back on production quickly and saves cost. The impact hammers are utilized in various applications, such as shifting sleeves, shearing pins, breaking disks, assisting with fishing operations and scale removal; in fact, any application where high frequency localized impacts are required. The tool’s impact force can be adjusted to accommodate the specific parameters of an operation. Its maximum capacity is up to 80,000 lb (36,000kg) per impact depending on tool size. The impact hammers enable operators to cost-effectively remove a wireline-retrievable packer (WRP), where conventional wireline techniques have failed and jars had proved impractical. The design allows adjustment of the impact force by manipulating the tension or compression weight on the tool. This maximizes operational efficiency, by enabling the impact hammer to function in numerous situations and the individual up and down hammer components enable the BHA design to accommodate specific jarring direction.
- Production and Well Operations > Well Intervention > Through tubing well intervention (0.70)
- Well Drilling > Wellbore Design > Wellbore integrity (0.68)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Inhibition and remediation of hydrates, scale, paraffin / wax and asphaltene (0.68)
- (3 more...)
Abstract Unconventional reservoirs are an increasingly important part of the hydrocarbon production pool in North America. Since reservoir conditions typically mandate the use of hydraulic fracturing for economical production results, a significant amount of resources are focused on making the fracturing process faster, more efficient and lower its environmental impact. This operational review focuses on a novel technique to rapidly perform targeted annular hydraulic fractures by deploying an activation tool on coiled tubing (CT) to open frac sleeves in a horizontal well. The paper covers results from the first operation of its kind in the United States – where a total of 48 stages were fractured in approximately 100 hours of operational time. The new technology does not involve dropping balls or setting composite plugs to isolate stages. Rather, the technique utilizes frac sleeves that are swiftly activated using a CT bottomhole assembly. The sleeves can be cemented in place if desired and have a full-bore internal diameter that does not require post-treatment composite plug millouts, further reducing overall completion time and efficiency. The operator preferred this method due to its targeted nature, efficiency and potential fluid savings. As opposed to multi- cluster fracturing methods (such as ‘plug-and-perf"), a single entry point during the frac job promotes increased fluid velocity, allowing for a more aggressive sand ramp and reduced required hydraulic horsepower. Similarly, the single entry point ensures that a fracture is generated at each port, as opposed to the possibility that some clusters are not treated. In addition, since no composite plugs or diverting devices are required to be pumped down the wellbore, water usage is reduced considerably. The system, already used in thousands of fracturing stages in Canada, speeds up the completion process, uses less fluid, minimizes risks, and reduces overall downtime.
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- North America > United States > Gulf of Mexico > Ellenburger Formation (0.99)
Abstract Traditional slickline work usually encompasses basic mechanical manipulation for downhole intervention work. In the recent past, a variety of battery-powered downhole tools have emerged in the market, providing additional deepwater solutions for the industry. These tools include the extended-reach downhole power unit and the smart release tool. The downhole electrical power unit is an electro-mechanical setting tool that uses a timer activation switch to begin the setting process for a variety of downhole tools. The smart release tool provides a timer-based mechanism to release the deployment wire from the downhole toolstring, eliminating the exposures associated with dropping a cutter in the event of a stuck tool. These tools can be conveyed on slickline for a variety of intervention solutions, including setting tubing plugs and packers, pulling subsea tree plugs, setting pressure gauges in tubing profiles, and providing a mechanical release in highly-deviated, extended-reach wellbores. This paper discusses specific well-intervention case histories using the downhole electrical power unit and the smart release tool. In the first case history, the downhole electrical power unit was used to set a packer assembly during a safety- valve repair. The smart release tool was used to soft set memory pressure gauges in wells without functioning, permanent downhole gauges, eliminating the need for jar action that could damage the gauges. Adaptations were made to the existing tool designs to respond to the well-specific challenges. These case histories demonstrate applications in which the electro-mechanical timer-activated tools have provided solutions for deepwater Gulf of Mexico well-intervention projects. The discussion includes lessons learned from previous project designs, development of operational best practices, and possible future applications to extend the role of slickline in deepwater operations. Applications may include the use of the downhole power unit to set packers and bridge plugs in conjunction with memory logging tools to correlate depth, as well as continued use of the smart release tool to minimize risks associated with downhole mechanical evaluation and memory data acquisition.
Coiled Tubing Reduces Stimulation Cycle Time by More Than 50% in Multilayer Wells in Russia
Yudin, A.. (Schlumberger) | Burdin, K.. (Schlumberger) | Yanchuk, D.. (Schlumberger) | Nikitin, A.. (Rosneft) | Bataman, I.. (Rosneft) | Serdyuk, A.. (Rosneft) | Mogutov, N.. (Rosneft) | Sitdikov, S.. (Rosneft)
Abstract Traditionally, coiled tubing (CT) in Russia has had very limited service diversity. Its use has been concentrated at wellbore cleanouts and nitrogen kickoffs after fracturing treatments. We used coiled tubing equipment and technologies to supplement stimulation operations in one of the world’s largest oil fields, Priobskoe, which has up to five separate layers per well. Conventionally, well completions here have involved complicated workover operations with tubing, packers, and wireline perforating after each stimulated layer. Average wells with three layers took 30 days to complete. CT provided a significant improvement in completion efficiency, reducing the cycle time to just 10 to 12 days. The first option of the completion and stimulation technology assumed "through casing" operations, eliminating the use of frac strings and a packer, which is a significant achievement under Russian regulations. This was done with a 4-in.-OD perforator and casing with increased strength. A year later, a second option for the technology was introduced to operate on regular strength casing through tubing. A slimmer abrasive perforator that could fit into the packer’s internal bore developed for this option was particularly effective for sidetrack and horizontal completions. In total, 95 wells were analyzed with more than 250 stimulation stages. This includes an operational and technical review of the tools and techniques used to compare the efficiency of the whole cycle of completion, resources requirements and amount of risks and non-productive time associated. Also a productivity comparison of CT combined with fracturing technology versus standard process of wireline/workover/stimulation sequence will be given.
- Europe (1.00)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug (0.49)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Well Completion > Completion Installation and Operations > Perforating (1.00)
- Well Completion > Completion Installation and Operations > Coiled tubing operations (1.00)
- Production and Well Operations > Well Intervention (1.00)
Abstract Remedial Sand Control is a challenging operation that requires economic judgment especially in brownfields. The operation turns into a greater challenge when the well, that needs to have a damaged gravel pack screen repaired is a sub hydrostatic well. We carried out pioneering repair project that was simple and cost-effective with minimum logistics using thru-tubing sand control. This method adapts thru-tubing tool advantages of coiled tubing to convey and set a smaller sand screen in a damaged gravel pack bore. The operation started by cleaning out in the deviated wellbore, controlling the well from kicks and deploying a long sand screen string in open-well conditions. To use this technique, two main challenges had to be solved. First, a long sand screen string had to be deployed into the wellbore on a production platform without the assistance of the derrick or platform crane. We used a two-stage self-skidding jacking frame with a 4-ton hydraulic winch to deploy the screen string into the well. Each un-deployed component of the screen string was lifted up from the storage rack with an elevator and connected with the string in the wellbore above the Christmas tree by a hydraulic tong. The installed string was held above the Christmas tree by a pneumatic slip and bowl mechanism. Second, the method must control the well from unexpected kicks while the sand screen is being deployed. We used hydraulic hydraulic well control method, which involves spotting "damaged free" lost-circulation material (LCM) fluid along target intervals and topping up with kill fluid, we also prepared a mechanical solution as a back up during job execution.
- North America > United States (0.46)
- Asia > Brunei (0.29)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Completion > Sand Control > Screen selection (1.00)
- Well Completion > Sand Control > Gravel pack design & evaluation (1.00)
- (2 more...)
Abstract The majority of the reservoirs in a study field in Indonesia are gas producers with water. The average production is more than 650 MMscf/D with 11,000 BWPD. The reservoirs are characterized as multilayered sandstone water-sensitive formations with permeability ranging from 0.1 md to 2 darcy. The measured depths (MD) of the perforated producing zones extend from 9,400 to 11,100 ft, with an average reservoir bottomhole temperature of 240°F (115°C). The study field has experienced significant water breakthrough in recent years, which has led to adrastic reduction in the total gas production per well. To increase gas production, it is required toreduce the water-gas ratio (WGR) to prevent the water-source reservoirs from killing the other producing layers and to stabilize the well’s flowing conditions. This could be achieved by shutting off the undesired water production. The main challenge of the study field is the number of reservoirsopened per well (>30 perforated reservoirs), with short distances between the perforated zones. Mechanical isolation was impossible in these cases because it would create restrictions during future interventions. A multidisciplinary group developed an innovative solution to shut off the water in these wells. The solution included a straddle system that consist of an inflatable retrievable bridge plug used as bottom isolation and an inflatable packer conveyed with coiled tubing (CT) as upper isolation, combined with a chemical water-shutoff treatment. The system was successful in shutting off the watered-outsands while keeping the upper reservoirs producing to date. This CT placement technique opened many opportunities for selective water-shutoff treatments of middle zones. This paper discusses the methodology of the job design, with a detailed operation sequence and results obtained from the field, including production results of some of the treatments pumped in the study field.
Initial Deployment of a New Design One-Trip Straddle System Resolves High Pressure Cross-Flow Problem in Water Injection Well in Algeria
Addoun, M.. (Organisation Ourhoud) | Maraf, K.. (Organisation Ourhoud) | Tighe, M.. (Organisation Ourhoud) | Bramwell, J.. (Weatherford) | Snaas, A.. (Weatherford)
Abstract The Ourhoud Field is located in Eastern Algeria and has some 60 producing wells with average production of approximately 600 m/d/well (3,750 bopd/well). Pressure maintenance and production drive is provided by means of water injection at a total rate of some 55,000 m/d (345,000 bwpd), and gas injection at 106 mmscfd. One water injection well provided problems to the continued effectiveness of the water injection program, because a thin isolated layer was acting as a thief zone taking some 30% of the injected water. When injection was shut down, the zone would crossflow into the zones above and below it at a rate of some 550 m/d (3,460 bwpd). In order to correct this problem a straddle system was needed to shut-off this zone, allowing all of the injected water to enter the two desired layers thereby increasing both the volume displaced into these layers and the production rate of surrounding wells. After a detailed review of available straddle options to shut-off the zone in the 7″ monobore completion, it was decided that a single trip system would provide the best chance of success by reducing the number of well entries required, the installation time, and the likelihood that continued shut-in cross-flow would have an adverse effect on a conventional two-trip straddle installation due to the protracted operation time. The chosen one-trip straddle (to set and retrieve) was a newly designed tool which had a model available in the required 7″ size that had undergone rigorous testing, but had not yet been used in the field. After extensive review of the design and testing of the tool, and evaluation of the risks associated with deploying a new design straddle against the advantages of a single trip installation, it was decided to run the first 7″ one-trip straddle on electric line in the well. In this paper the authors will review the well specifics, the design and operation of the single trip straddle, and the decision making process which resulted in its first installation. They will go on to describe the installation process in detail, and review the positive results achieved by the successful shut-off of the cross-flow situation.
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Abstract Multi-stage proppant fracturing of horizontal wells has changed the economic landscape of the North American Oil and Gas Industry. Open-hole ball drop completion systems, are an economic solution for many operators, however alternative completions systems are emerging into the marketplace. This paper will describe a novel CT actuated, predominantly cased hole, CT Frac Sleeve completion. This paper will explain how it works, and how operators are taking advantage of several new capabilities not available in other completion systems. The new capabilities that will be described include better placement control of each treatment and an unlimited number of treatment stages resulting in better drainage of the reservoir. In addition, this paper will describe how CT and its bottom-hole assembly are not only required to sequentially open each of the CT Frac Sleeves, for each stimulation treatment, but add additional value to the system. How CT enables quick recovery from screen outs, freeing the fracture treatment process engineer to optimize the treatments without the risk of large financial penalties. Further how CT is used to accurately measure the bottom hole pressure during the treatment, also aiding the engineer to optimize the stimulation treatment, ultimately delivering a better stimulation treatment and improving the productivity of the reservoir. Finally, the paper will discuss how the CT BHA has contingent capabilities, as it is equipped with a sand jet perforating device.
- North America > United States (0.69)
- North America > Canada > Alberta (0.29)
- North America > Canada > Saskatchewan > Williston Basin > Bakken Shale Formation (0.94)
- North America > Canada > Manitoba > Williston Basin > Bakken Shale Formation (0.94)
Abstract The well stimulation and water shut off (WSO) job in the carbonate reservoir of Ghawar field in Saudi Arabia is becoming increasingly challenging, considering the complex well completion. Many challenges are therefore encountered during coiled tubing (CT) interventions when trying either to permanently shutdown water production or to temporarily isolate the water zone to stimulate the oil intervals. In fact, the lack of real-time bottom-hole control of mechanical or chemical diverters caused these jobs to fail with conventional CT strings, which eventually called for costly solutions using workover rigs. This paper describes multiple shortfalls of previous WSO and matrix stimulation jobs, and how this trend is reversed after the emergence of the fiber optic enabled CT (FOECT) string with real-time downhole measurement sensors. The permanent zonal isolation utilizing an inflatable packer with cement plug is now possible with greater accuracy and enhanced success ratio even in wells with complex completions. The availability of a real-time casing collar locator (CCL), bottom-hole temperature (BHT) and differential pressure readings enables adequate control of packer setting depth and inflation, and optimization of the cement design and its injection. The temporarily zonal isolation using chemical diverters can now be assessed real-time with the Distributed Temperature Survey (DTS). The stimulation fluids will not be pumped unless the isolation of the water zone is confirmed. The CT acid job can be now optimized by eliminating the risk of losing acid into the water intervals and by ensuring a uniform acid coverage across the oil zones with DTS. This method was validated with the wireline log run just before the CT job. Challenges, design, execution and results of zonal isolation interventions with both conventional CT and FOECT are detailed in this paper to demonstrate that this type of CT job becomes more successful with the FOECT.
- North America > United States (0.94)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate (0.24)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Zakum Concession > Zakum Field > Upper Zakum Field > Thamama Group Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Lower Fadhili Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Khuff D Formation (0.99)
- (5 more...)
- Well Completion > Well Integrity > Zonal isolation (1.00)
- Well Completion > Completion Installation and Operations > Coiled tubing operations (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Production and Well Operations > Well Intervention (1.00)
Abstract For a number of years one of the main areas being developed has been multilateral wells to better access the reservoir. One of the greatest challenges in operating an efficient multilateral well is having control of where any water production is coming from. Effectively managing produced water can bring obvious benefits to the economics of a well. One tool that has not been exploited for this type of application is swellable packers. Coiled Tubing and Swellable Packer technologies were recently combined on a land-based operation in Holland to successfully isolate a water-producing leg of a well lateral. The operator asked for a proposed completion solution after a previous attempt to isolate the lateral had proved unsuccessful. The proposed solution was designed to straddle the lateral entry/exit with a scab liner, isolated and anchored at either end by water-swellable packers. The straddle was required to seal inside the main bore casing and withstand a differential pressure at well operating temperatures. Swellable packers were selected from the various proven openhole isolation devices available to the industry to provide the zonal isolation required in the multi-zone intervals. This was the first swellable straddle completion in Holland in a watered out, commingled gas environment in which isolation would be contained solely by swellable packers. The water producing lateral was successfully straddled using two water swellable packers run with base pipe between the two packers. In this application the Swellable Straddle was deployed in conjunction with an additional mechanical packer to anchor the straddle whilst the swelling process in the aqueous environment took place. A subsequent intervention with coiled tubing and a resettable Inflatable Test Packer confirmed the straddle had successfully sealed and had isolated the water producing lateral. This paper presents a solution to the challenges of isolating laterals using swellable packers and coiled tubing, and how to verify that the junction has been successfully isolated.
- North America > United States > Texas (0.29)
- Europe > Netherlands (0.28)
- Well Drilling > Drilling Operations (1.00)
- Well Completion > Well Integrity > Zonal isolation (1.00)