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Results
Abstract Sealing technologies provide a vital role in a wide range of applications no more so than in the design and development of Retrievable Bridge Plugs (RBP) where performance is a vital safety and operational consideration. Moreover, for workover operations using RBPs it is also essential that deployment and recovery are equally as reliable as the pressure and temperature performance of the plug. Traditional retrievable bridge plugs based on solid elastomeric seals have been the mainstay of well intervention since the 1940’s. However, the long-term shift towards gas production, higher pressures, higher temperatures and increased regulatory standards means these systems can no longer provide the performance the industry demands. New innovative technologies are needed to bridge this gap and this paper provides evidence of once such technology with the potential to service the next era of exploration and production. The paper explores some of the operational and practical limitations of traditional solid elastomer sealing technology for RBPs and introduces a new type of hybrid metal-polymer seal offering significantly improved sealing performance, larger running clearances and enhanced reliability. The new seal technology is described alongside experimental data on the seal’s performance and operational configuration.
Abstract A stimulation optimization study was recently conducted to design the acid recipes and execution programs for a new carbonate field in Abu Dhabi. The following paper outlines lessons learned and technical considerations that can improve the stimulation design of carbonate reservoirs. This particular field has a variety of extended horizontal completions ranging from open hole drains to liners with inflow control devices (ICDs). The following testing format can lead to immediate cost savings and long-term production increases in both green and brown fields. The Reservoir and Operation teams leveraged their expertise to place science firmly behind this important aspect of bringing a new field online. By being exact about the recipe testing procedure, the team made technical improvements to the existing recipes while also lowering the cost of stimulation.
- North America > United States > Texas (0.71)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.36)
No-damage Stimulation Based on Residual-free Diverting Fluid for Carbonate Reservoir
Shi, Y.. (Research Institute of Petroleum Exploration & Development, CNPC) | Yang, X.. (Research Institute of Petroleum Exploration & Development, CNPC) | Zhou, F.. (Research Institute of Petroleum Exploration & Development, CNPC) | Gao, Y.. (Research Institute of Petroleum Exploration & Development, CNPC) | Lian, S.. (Research Institute of Petroleum Exploration & Development, CNPC) | li, x.. (Research Institute of Petroleum Exploration & Development, CNPC) | Han, X.. (Research Institute of Petroleum Exploration & Development, CNPC)
Abstract Horizontal well and acid stimulation are the essential technologies for the development of complex carbonate reservoir. However, it is extremely difficult to conduct effective stimulation in horizontal wells with a long interval because the traditional acid systems without diverting performance can only flow into the high permeable formations, leaving the damaged formation untreated. That is why the long interval wells with high heterogeneity need to be stimulated by diverting acid system. Many diverting acid systems or diverting agents have been developed in recent decades. Whereas, last generation diverting systems always cause serious damage to formation, such as gelled acid based on polymer. In addition, many systems will lose their diverting performance at high temperature. This paper studied some kind of residual-free fluid systems for both acid treatment and fracturing in order to develop no-damage/reduced-damage and high effective stimulation techniques for long interval wells. It is designed to conduct uniform stimulation in a long distance wellbore with the assistance of diverting performance of some special chemical agents, which can work at high termperature and leave no damage in formation. No-damage stimulation includes: Temperature-controlled deep-diverting acid system (TCA); pH-controlled self-diverting acid system (DCA), and Fracture reorientation technology based on degradable fiber (RDF). This series of technologies can generate fracture networks to enhance the stimulated reservoir volume through fracture reorientation and diverting acidizing with the help of special residual-free fluid system, leaving no damage in formation. This series of techniques had been applied on 921 wells from 10 oil/gas fields in China and 7 oil/gas fields in Kazakhstan, Iran, Iraq, Syria and Turkmenistan.
- Asia > China (1.00)
- Asia > Middle East > Syria (0.25)
- Asia > Middle East > Iraq (0.25)
- Asia > Middle East > Iran (0.25)
- Asia > China > Xinjiang Uyghur Autonomous Region > Tarim Basin (0.99)
- Asia > China > Heilongjiang > Songliao Basin > Daqing Field > Yian Formation (0.99)
- Asia > China > Heilongjiang > Songliao Basin > Daqing Field > Mingshui Formation (0.99)
- North America > United States > Louisiana > China Field (0.97)
Abstract The main objective of the paper is to present the possibility of non-contact approach based on electrical plasma in downhole milling or cutting operations. The features of this approach can be beneficial for a variety of Well Intervention applications characteristic for Middle East region. These applications include slot recovery, side-tracking, pipe recovery and several others. The presented approach utilizes thermal electrical plasma capable to disintegrate a variety of materials (steel, cement, rock) with the same tool. Milling or cutting using this approach is based on a hybridized plasmachemical and thermochemical processes resulting fast metal degradation and removal in water steam environment. The main processes responsible for the rate and effectivity of steel/cement removal are oxidative processes as well as melting and evaporation. This non-contact approach utilizing coiled tubing (CT) technology brings also improved reliability by minimization of wear and tear of the tool itself. Based on its features, the technology can bring the following benefits into Slot recovery application area: Multicasing milling in fewer trips 100% rigless operation – Light Well Intervention Vessel offering flexible use and satisfying immediate needs Generation of small swarf (no mechanical stuck, less viscous and cheaper fluids) Reduction of HSE-related risks due to reduced tripping and automated CT system Reduction of issues with fluid management due to simplified handling with milled material Shortening of the whole process due to its structural simplification Similarly, the mentioned features can be used also for other potential applications including: Multi-lateral side-tracking Pipe recovery of stuck BHA Repair/replacement of damaged casing Wellhead retrieval Moreover, after development and modifications of the tool geometry, it can provide an efficient substitution of conventional junk/fish milling tools.
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Zakum Concession > Zakum Field > Lower Zakum Field > Thamama Group Formation (0.94)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Ghasha Concession > Umm Shaif and Nasr Block > Umm Shaif and Nasr Field > Umm Shaif Field > Arab Formation (0.94)
Acid Systems and ICD Design Considerations For Stimulation
Edmonstone, Graham (Zakum Development Company (ZADCO)) | Jackson, Alfred (Zakum Development Company (ZADCO)) | Kofoed, Curtis (Zakum Development Company (ZADCO)) | Shuchart, Chris (ExxonMobil Upstream Research Company (URC)) | Troshko, Andrey (ExxonMobil Upstream Research Company (URC))
Abstract The recent industry development of drilling ERD wells with horizontal laterals in the reservoir of 10,000 ft. or more has led to a greater use of passive flow control devices and swell packers to achieve the desired inflow or outflow profiles. Another desire is to perform stimulation treatments of the lateral especially in tight carbonate formations. However, such treatments can create high velocities through the Inflow Control Devices (ICDs) that inevitably leads to high turbulence and wall shear stress in the ICD which can cause severe erosion and corrosion of commonly used materials. There appears to be little experience and associated knowledge on corrosion mitigation to ensure ICD integrity after well stimulation. This paper will attempt to address such concerns through: Discussing and analysing ICD design considerations to avoid high corrosion areas and selection of high alloy materials to resist corrosion. Selection of appropriate acid system and method to prevent corrosion. Laboratory testing of acid formulations under high wall shear conditions as predicted from Computational Fluid Dynamics (CFD) of the ICD design at reservoir conditions. Laboratory measurements of the performance of corrosion protection additives in acid formulations under wall shear conditions. Other possible mitigation efforts to reduce the need for stimulation treatments. Each of these factors presents limitations which either restricts the use of aggressive acid systems or requires alternative acid systems that can lead to increased treatment cost and/or sub-optimal stimulation of the reservoir through the ICDs. This paper discusses one producing company's effort to systematically improve the overall performance of stimulation through ICDs while maintaining the integrity of the lower completion liner.
Enhancing Reservoir Surveillance and Production Sustainability Through Live Digital Slickline
Said, M. Bou (Abu Dhabi Marine Operating Co.) | Bilbeisi, J. M. (Abu Dhabi Marine Operating Co.) | Mansouri, T.. (Abu Dhabi Marine Operating Co.) | Respecia, B. S. (Abu Dhabi Marine Operating Co.) | Assagaf, M.. (Schlumberger) | Cocagne, M.. (Schlumberger) | Ambo, L.. (Schlumberger)
Abstract Reservoir Surveillance is made increasingly difficult in mature offshore oilfields that contain a large number of wells with all associated infrastructure. While logging requirements are increasing in order to sustain production from the field and maintain well integrity, the production requirement is increasing and the operational cost has to decrease. These challenges are additional to the existing constraints due to resource limitations in an offshore environment: winch boats for equipment movement, slickline units for downhole safety valve retrieval and tubing checks as well as offshore living accommodation limitations are major factors any of which can cause a halt of rigless logging campaigns. A new digital slickline unit was used to replace the conventional practice for rigless wireline logging operations in offshore fields (wellhead towers). The old method involved a slickline unit to perform the pre-job and post job work. That's in addition to the logging unit that performs the required production logging job. This process involved a lot of winch boat moves, personnel and shut in days resulting in loss of production between moves. This digital slickline unit combines the capabilities of a slickline unit and a logging unit. The type of slickline it uses allows sending commands to logging tools downhole and receiving data on the surface data acquisition system while logging. The new approach had multiple operational, financial and HSE&Q impacts. Operationally, performing production logging operations using this digital slickline unit minimized logistics compared to conventional production logging (4 lifting loads Vs. 14 lifting loads). It has also reduced the operation time and trips to and from wellhead towers which resulted in reducing production losses. It also helped achieving the increasing annual logging and slickline KPI's without compromising data QC. Furthermore, HSE&Q was addressed by providing a solution for some integrity concerns related to wells being left with no downhole safety valves between slickline and logging unit movements. Moreover, the probability of incidents caused by improper handling of equipment and tripping/slipping hazards was reduced and most importantly, the option of Medevac by chopper became available in emergency cases due to the reduction in the occupied tower area. This breakthrough in logging operations from offshore wellhead towers enhanced the operational quality and reduced cost. It represents a part of the continuous efforts to reshape the concept of production and reservoir surveillance (which includes well testing, pressure surveys, etc) by applying new technologies and following new approaches to allow fulfilling larger requirements without making compromises on HSE&Q, production requirement and cost efficiency.
- Well Completion > Completion Installation and 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)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
Abstract For the first time in ADCO, and the UAE, a window was opened in Super 13CR 7 inch casing in well QW-XY. Extensive pre-job planning, two way communication between ADCO and Baker Hughes, and flawless job execution were the key factors for the success which allowed ADCO to immediately reach the reservoir, saving significant time and costs versus the typical window in the 9 5/8 inch casing. The main objective was to avoid cutting the window through the 9 5/8 inch casing to leave space for the ESP completion to be installed deeper for enhanced oil recovery and extending the well life. This also saved resources to drill 8-12/" section including OBM and 7 inch liner and its related accessories that were going to be required in case of the 9 5/8 inch casing window. The team decided to take the challenge presented in the stiffness of the Super 13CR material and the deviation at the window depth to save Rig days and resources. This operation utilized Path-Master whip stock and Silverback milling technology to successfully open the window and drill the required rat-hole in one trip. Another reaming trip was carried out to ensure seamless reentry with the drilling BHA later on. Teamwork and cooperation are the keywords that made this operation possible; with Baker Hughes technology and ADCO's innovation. This paper describes the first ever window opeing thorugh 7in S13CR in the UAE. This includes planning, risk assessment, the challeges, procedures and the conclusion. A detailed cost-benefit analysis is presented between 9-5/8" convetional window opeing compared with 7in window.
Retrospective Study and Multidisciplinary Optimization Workflow to Address Production Challenges in Ultralow Permeability, Tectonically Active, HPHT Dolomite Formation in Northern Kuwait
Kanneganti, Kousic (Schlumberger) | Mahesh, Arathi L. (Schlumberger) | Barasia, Ankur (Schlumberger) | Cabrera Salavarria, Jose Ramon (Schlumberger) | Dananjaya Wiryoutomo, Marenda (Schlumberger) | Mohamed Abdul Samad, Zamzam (Kuwait Oil Company) | Fidan, Erkan (Kuwait Oil Company) | Aziz Al-Failakawi, Abdul (Kuwait Oil Company)
Abstract The deep high pressure/high temperature (HPHT) dolomite formation in Northern Kuwait has been a challenge with varied production, attributable to reservoir heterogeneity. Due to the tight nature of these rocks, matrix acidizing may not produce desired effects, thus requiring hydraulic fracturing to produce at economic rates. However, the tectonic setting in high stress environment has resulted in subpar success and inconsistent results from stimulation treatments in matrix and hydraulic fracturing applications. This paper presents a multidisciplinary approach to address the limited success in the Northern Kuwait Dolomites. An integrated petrophysical evaluation of the current wells will be followed with multi-well Heterogeneous Rock Analysis (HRA), to evaluate the reservoir heterogeneity across the field and identify the ‘sweet spots’ for future drilling locations. Evaluation and lessons learnt from the past stimulation treatments, will be used to understand geo-mechanical challenges and to help calibrate the Mechanical Earth Model (MEM) for implementation in the future wells. Finally, using a reservoir-centric stimulation design tool, stimulation type (acid fracturing vs proppant fracturing) and stimulation design optimization for future wells will be developed. A reservoir-level petrophysical evaluation of the existing wells was performed and compared to understand the reservoir heterogeneity vis. a vis. production potential. Multiple rock classes were identified within the tight dolomite interval, with a gross thickness of ~250 ft. Starting with log based MEM, results from the image log interpretation and the field observations/measurements from fracture diagnostic tests (Decline analysis, Calibration injection) were used in calibrating the MEM and mapping the Completion Quality (CQ) heterogeneity across the field. This has led to a reservoir-level understanding, which can enable planning optimal well locations, target interval and subsequent well placement/completions methodology. Finally, using the reservoir-centric design tool, an optimum design to effectively stimulate the ultralow-permeability dolomites was determined. The optimization workflow did not only include a single-faceted approach of fracture modeling, but also encompassed a production forecast using the integrated numerical reservoir simulator. Lessons learnt from the optimization workflow were further extended to designing horizontal wells (landing point, trajectory for optimal stimulation geometry), and hence to aid in field development strategy. Using the multidisciplinary unconventional workflow, the heterogeneity in reservoir quality and completion quality was evaluated, both along the wellbore and spatially. In essence, we found that natural fractures along with high Critical Net Pay (CNP) allows you to vertically connect with good RQ and thus, is required for success in these tight reservoirs. Following which, reservoir-centric stimulation design tool enabled optimization of completion and stimulation design in a holistic approach, to maximize appraisal and production opportunities.
- North America > United States > Texas (1.00)
- Asia > Middle East > Kuwait (0.93)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying (0.93)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (25 more...)
Well Performance Improvement Using Complex Nano Fluids
Kutty, Shanof Mohamed (ADMA OPCO) | Kuliyev, Myrat (ADMA OPCO) | Hussein, Mohamed Abdelsalam (ADMA OPCO) | Chitre, Sunil (ADMA OPCO) | Mustafa, Hammad (ADMA OPCO) | Penny, Glenn (CESI Chemical - Flotek Company) | Wehbeh, Jamal (CESI Chemical - Flotek Company) | Germack, David (CESI Chemical - Flotek Company) | Shedd, Daniel (CESI Chemical - Flotek Company) | Lelenwa, Chilezie (CESI Chemical - Flotek Company)
Abstract ADMA OPCO has started operations for a full field development plan in a green field located in offshore Abu Dhabi. All reservoirs are carbonates (dolomites and limestones) and thus acid stimulation is required post well completion in order to increase the well production/injection rate. During the planning stage, an extensive acid recipe study was carried out to formulate stimulation treatments to meet the challenging complexities of the reservoirs, high downhole temperatures and long corrosion protection time. Several lab tests were carried out to formulate all the acid recipes. While in quest of new technology, an additive called ‘Complex Nano Fluid’ was introduced in the acid recipes based on proven case histories from around the world. This was also confirmed with the lab tests using ADMA reservoir crude and core samples. It is expected that by including nano fluids in matrix stimulation fluids, the overall productivity enhancement will be approximately 40% greater than conventional treatment approches. Most of the tests were performed in Abu Dhabi, however special wormholing tests with CT scan were done in a lab in Houston to evaluate the effectiveness of nano fluids on core samples. This paper details the acid recipe work flow process, the different lab tests that were carried out to formulate the acid recipes, mechanism of complex nano fluid and its advantages.
- North America > United States (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.55)
Abstract The use of mechanical diverters in the oil and gas industry has been a common practice for decades, typically deploying perf ball sealers, degradeable balls, rock salt, dissolvable flakes, and incorporating downhole equipment such as sliding sleeves or straddle-packer systems. With multiple stage operations and horizontal wells becoming the industry norm, there is a need for a more permanent and reliable technology that is easily deployable and will seal previously stimulated perforations and zones from untreated perforations. This paper describes case histories from horizontal Marcellus Shale wells treated with degradable diversion materials applicable at a broad bottom-hole temperature range, maintains integrity under treating pressures and remains in place for the entire duration of well completion operations. There are a number of scenarios for which biodegradable materials are applicable: zonal isolation for horizontal wells with multiple perforation clusters, vertical wells treated through tubing where bridge plugs cannot be used, sealing off perforations for re-stimulation treatments as opposed to squeezing the perfs, and sealing off perforations after treating through coiled-tubing. The results from the case study well treated in the Uintah Basin in Utah on the Wasatch formation showed compelling evidence that temporary mechanical bridging agents can effectively replace bridge plugs and maintain zonal isolation. The concentrations of the diverter system used were optimized during the treatments and achieved typical pressure increases of 200-500 psi when deployed. The information presented in this paper will show the capabilities of using this material and the potential applications for multiple stage stimulation treatments, allowing for optimal zonal coverage and increased operational efficiency. The pressure responses from the treatments show the ability of the materials to seal the perforation clusters taking the majority of fluid and allow for diversion to understimulated perforation clusters. The production results from this candidate well additionally showed production rates higher than neighboring wells and wells typical for that area.
- North America > United States > Utah (0.55)
- North America > United States > Pennsylvania (0.55)
- North America > United States > Wyoming > Uinta Basin (0.99)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- (8 more...)