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Collaborating Authors
Drilling fluid management & disposal
Summary The Schoonebeek heavy-oil field was first developed by Nederlandse Aardolie Maatschappij B.V. (NAM) in the late 1940s. Because of economics, it was abandoned in 1996. In 2008, the Schoonebeek Redevelopment Project, using a gravity-assisted-steamflood (GASF) design concept, was initiated with 73 wells (44 producers, 25 injectors, and 4 observation wells). Steam injection and cool-down cycles subject a cement sheath to some of the most severe load conditions in the industry. Wellbore thermal modeling predicted that surface and production sections would experience temperatures in excess of 285°C (545°F) and considerable stress across weak formations. A key design requirement was long-term integrity of the cement sheath over an expected 25- to 30-year field life span. Complicating this requirement was the need for lightweight cementing systems, because lost-circulation issues were expected in both hole sections, particularly in the mechanically weak Bentheim sandstone. The long-term integrity challenge was divided into chemical and mechanical elements. Prior research on high-temperature cement performance by the operator provided necessary guidance for this project. Laboratory mechanical and analytical tests were conducted to confirm the high-temperature stability of the chosen design. In addition to using lightweight components, foaming the slurry allowed the density, mechanical, and economic targets to be met. A standardized logistical plan was put in place to allow use of the same base blend for the entire well, adjusted as needed, using liquid additives, and applying the foaming process when necessary. This single-blend approach greatly simplified bulk-handling logistics, allowing use of dedicated bulk-handling equipment. The first well was constructed in January 2009; all 73 wells have been successfully cemented to surface. The steaming process, initiated in May 2011, has progressed with no well integrity issues to date.
- North America > United States (1.00)
- Europe > Netherlands > North Sea > Dutch Sector (0.50)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (1.00)
- Geology > Geological Subdiscipline > Geomechanics (0.93)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.35)
- Europe > Netherlands > North Sea > Dutch Sector > Schoonebeek License > Bentheim Sandstone Formation (0.99)
- Europe > Netherlands > North Sea > Dutch Sector > Schoonebeek Field > Bentheim Sandstone Formation (0.99)
- Europe > Netherlands > Coevorden Field > Z3 Carbonate Formation (0.98)
- (6 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Operations (1.00)
- (7 more...)
Abstract The development of arctic resources requires wells to be drilled, cased, andcemented through permafrost. Permafrost presents unique challenges, especiallyto cementing operations, requiring a cement system with the capability toperform in the subfreezing permafrost environment. The performance required isthat the cement provides isolation, exhibits low heat of hydration, and setswith sufficient strength to provide casing support. There are also specifictesting requirements detailed in API recommended practices. In the polar region, there are several approaches used in the design of cementsystems. The approaches used in Russia, Canada, and USA (Alaska) areillustrated. The design considerations take into account local conditions andrequirements and use knowledge from cementing practices employed in thedrilling industry. It is important to understand the current cementing practices in use withinthe arctic region. This will allow future improvements as more developmenttakes place and the resources become exploited. Introduction To be successful, hydrocarbon resource development in arctic regions mustmeet the challenges posed by drilling, casing, and cementing wells throughpermafrost layers in the remote arctic environment. The Russian Far East, forexample, is almost completely covered in permafrost and holds significant gasreserves that remain largely untapped due to the remoteness of the area and thecomplexity of drilling through the permafrost layers. Offshore operations areadditionally impacted by sea ice, which does not directly affect cementingoperations; however, the short operational window certainly requires detailedplanning and reliable performance. The remoteness of arctic locations affects all aspects of development, impacting overall logistics: access, timing, and materials delivery andstorage. In addition, several of the challenges faced during the initialdevelopment phases affect the subsequent cement job and cementing practices. These challenges need to be addressed as part of the overall development plan;they include borehole maintenance, casing centralization, and mud conditioningand removal, and all require careful consideration of the permafrost.
- Europe (1.00)
- North America > United States > Texas (0.46)
- North America > United States > Colorado (0.28)
- (2 more...)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
- Well Drilling > Casing and Cementing > Casing design (0.94)
Abstract One of the greatest challenges with respect to coal seam gas (CSG) wells in Queensland, Australia is the many loss zones encountered during drilling and cementing operations. Typical directional wells in the area are up to 2000 m measured depth (MD) and 1200 m true vertical depth (TVD). In some instances production enhancement by fracture stimulation is required and therefore high-strength cement is necessary while maintaining the lowest possible pressure on the formation and natural fractures. A trial was setup on a directional well pad where various methods of returning cement to surface were attempted. All three wells had similar well design, expected losses, and drilling times. The first well was unsuccessful and no cement was returned back inside the previous surface casing shoe. With the addition of a reactive spacer and more excess volume, cement inside the previous casing shoe was achieved on the second well. Both wells used standard 12-lbm/gal slurries. The third and final well on the pad required a step-change in the cement job design to achieve cement to surface. The most successful cementing job was achieved on the third well by redesigning the slurry to a lower density of 11 lbm/gal, without compromising set times, thixotropic properties, and high compressive strength. To improve equivalent circulating densities (ECD), the new slurry was designed with lower rheology. The slurry's low solids-to-water ratio (SWR) and large slurry volume, which precluded batch mixing, required the job to be mixed and pumped on-the-fly using an automated volumetric mixing system rather than using density mixing. This paper discusses the job preparation and technical details involving how the 11-lbm/gal cement slurry achieved a successful production casing cement job with returns to surface. With similar successes demonstrated on subsequent wells, this case history set a new standard in the field.
- Asia (1.00)
- North America > United States > Texas (0.28)
- Oceania > Australia > Queensland (0.25)
Abstract Cementing a string in one stage is a challenging task, especially in the presence of weak formations. Cement slurry losses during placement is highly possible if the equivalent circulating density (ECD) exceeds 82 pcf during placement. A conventional method to overcome this challenge is to use multi-stage cementing by setting the stage tool above the loss circulation zone. However, field data indicate that the tool can fail, thus causing serious delay and economic loss. In addition, stage tools are considered weak point and not good for long term seal. A second method for zonal isolation is to use low density cement. In this study, we present extensive lab evaluation of a low density system based on the use of hollow microspheres for one year at field conditions. The tests included one year mechanical properties measurement such as compressive strength development, Young's modulus and Poisson's ratio. The low-density system (70 pcf) was tested at 300 ºF. An earlier study has shown the suitability of using low density cement in the field, Al-Yami et al. (2007). However, there is no available Investigation in the literature about the durability of low density cement at higher temperature and at different operational scenarios. The finite element method was used to analyze the failure probability of HPHT wells over with time. At the variation of bottom whole pressure, the casing, cement, and formation system failure probability was studied for this type of cement. This paper introduces the operational envelope for this type of cement in order to achieve successful operations. Field cases were discussed to validate the results of this investigation.
- North America > United States > Texas (0.69)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate (0.28)
- North America > United States > New Mexico > San Juan Basin (0.99)
- North America > United States > Colorado > San Juan Basin (0.99)
- North America > United States > Arizona > San Juan Basin (0.99)
- (14 more...)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (0.94)
Abstract Offshore cementing poses many challenges across the world as drilling operations move towards deep-water and ultra-deep-water. As a new initiative of continuous improvement, a deep-water cementing peer review process was started early 2011. To this date, this team has reviewed more than 1200 deep-water cementing jobs in more than 30 countries worldwide. Plug cementing makes up nearly 53% of all the deep-water jobs reviewed. The majority of the cement plugs placed are for plug and abandonment purposes; however a significant part is for loss circulation, kick-off, or squeeze. Although plug cementing comprises a big portion of deep-water cementing, it often does not get the same level of attention as primary cementing. Specialized plug cementing software is used to design all cement plugs set in deep-water operations. The software simulates fluid interfaces, contamination during placement (both when the fluid is travelling down the pipe and when it is being placed in the annulus) and while pulling out of hole. As a final result, it provides the top of uncontaminated cement. Aside from proper job placement, good slurry design is very important. Cement slurries used for plug cementing need to be designed according to the objectives of the job. Several case histories will show lessons learned from the analysis of plug cementing operations in deep-water operations. As the industry and local regulations gets more stringent on the evaluation and acceptance of the barrier for well integrity, the success of setting a cement plug the first time is becoming ever more critical. Getting it right the first time easily saves several days of NPT resulting in savings of millions of dollars, especially in this deep-water environment. Appropriate focus on sound engineering practices and the use of the specialized software has improved reliability of setting cement plugs in deep-water and helps operators avoid costly remedial operations.
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Well Drilling > Casing and Cementing (1.00)
- Management > Professionalism, Training, and Education > Communities of practice (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Knowledge management (1.00)
Copyright 2012, Society of Petroleum Engineers This paper was prepared for presentation at the SPE Heavy Oil Conference Canada held in Calgary, Alberta, Canada, 12-14 June 2012. This paper was selected for presentation by an SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of SPE copyright. Abstract The drilling and completing of Infill wells (wells drilled amongst existing SAGD wells) is becoming common practice with many operators in North Eastern Alberta. These Infill wells pose numerous challenges that may not exist in the drilling and completing of a conventional SAGD well. In addition to conventional challenges such as lost circulation that need to be safely managed to have a successful completion strategy, the Infill wellbore has elevated temperatures and heat transfer rates due to contact with or close proximity to a steam chamber. There is no single, universal strategy used by operators to address and control these challenges, which require robust cementing solutions. This variation in clients' BHCT results is due in part to the drilling, and more specifically, the circulation strategy used.
- North America > United States > Texas (0.47)
- North America > Canada > Alberta > Census Division No. 6 > Calgary Metropolitan Region > Calgary (0.24)
- Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Thermal methods (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (0.92)
Abstract The two principal functions of oilwell cementing are to restrict fluid movement between zones within the formation and to bond and support the casing. Apart from these, the cement sheath also protects casing from corroding, protects the casing from shock loads when drilling deeper, and plugs lost circulation or thief zones. Once cement is placed in the wellbore, initial setting occurs wherein development of compressive strength becomes more important for further drilling operations. Early strength development is important to help ensure structural support to the casing and hydraulic and mechanical isolation of downhole intervals. Delays in strength development cause significant amounts of lost time because of the need to wait on cement (WOC). Typically, an accelerator is often used to enable early strength development in cement. It is desired that an accelerator should improve overall compressive strength without causing excessive gelation. Nanomaterials (being smaller in size and higher in surface area) are used in several fields, including catalysis, polymers, electronics, and biomedicals. Because of a higher surface area, these materials can also be used in oilwell cementing to accelerate the cement hydration process. Moreover, they are often required in small quantities. This paper documents a case in which nanosilica was used in cement formulations to develop high early strength. Nanosilica also helps enhance final compressive strength and helps control fluid loss. Using the correct quantity of nanosilica, it is possible to design cement slurry with low rheology and good mechanical properties while controlling fluid loss.
- Europe (0.48)
- North America > United States (0.29)
- Asia > Middle East > Saudi Arabia (0.29)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Well Drilling > Casing and Cementing > Cement formulation (chemistry, properties) (1.00)
Abstract Salt formations are common trap zones for prolific reservoirs. Recent discoveries in the Brazilian coast include light oil carbonate reservoirs below massive salt zones. Well construction challenges in such environments include salt creeping, leaching and proper zonal isolation. This article presents a comprehensive integrated methodology for cementing design which accounts for the following hydraulic aspects: Adequate fluid substitution design supported by numerical simulation considering two phase flow in eccentric annuli and lubrication theory Downhole pressures in the operational window considering free fall effects for deepwater environments Open hole volume prediction based on salt leaching phenomena due to the circulation of unsaturated fluids. Flow rate fluctuation as a result of free fall is considered Increase in salt concentration due to conduction effects after placement and its impact on slurry properties. The methodology is exemplified by two typical scenarios for offshore salt cementing in the Brazilian pre-salt cluster. Slurry design, slurry placement schedules and borehole stability considerations are addressed.
- South America > Brazil (1.00)
- Europe > Norway > Norwegian Sea (0.24)
- Geology > Structural Geology > Tectonics > Salt Tectonics (0.48)
- Geology > Mineral > Halide > Halite (0.35)
- Well Drilling > Drilling Operations (1.00)
- Production and Well Operations (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (0.94)
- (4 more...)
Cementing Unconsolidated Sandstone Formations with Coexisting Oil and Water
Robles, J.. (San Antonio Internacional) | Sapag, F.. (San Antonio Internacional) | Sanchez, L.. (San Antonio Internacional) | Morris, W.. (San Antonio Internacional) | Peacock, H.. (San Antonio Internacional) | Bravo, J.. (UTE Petr?leos Sudamericanos S.A. – NECON S.A.)
Abstract Oil wells with unconsolidated formations where oil and water coexist require special attention during drilling, well completion and production stages. This is the case of a heavy oilfield located in the Neuquina Basin, Argentina, where for many years, periodic cement squeeze jobs were needed to avoid near-wellbore water channeling. In addition to formation unconsolidation, this reservoir has high porosity and permeability as well as poor lithologycal barriers. When the top of the oil producing zone is perforated and evaluated by swabbing, viscous oil carrying formation sand is initially produced. After a short period of time (days), water cut rises to values close to 100 % promoted by the high mobility ratio. This response impedes a profitable production of these oil wells. After analyzing open and cased-hole logs, as well as production history data, the hypothesis for the short term water invasion was identified as near-wellbore channeling caused by sand production. This process was aided by formation weakening due to its interaction with drilling and completion fluids. The solution to this problem was based on a primary cementing procedure that included specially designed slurries containing polymeric admixtures. Effective formation isolation, bonding and near-wellbore consolidation was achieved by allowing these additives to leak-off into the unconsolidated formation. This paper presents the experimental tests performed to develop the procedure and the field results obtained after five successful cementing jobs. Sand production was significantly diminished and no cement repairs were needed after the first six months of production.
- South America > Argentina > Neuquén Province > Neuquén (0.67)
- South America > Argentina > Patagonia Region (0.49)
- North America > United States > Texas (0.47)
Abstract The primary goal of operators and drilling contractors is to safely, economically, and efficiently drill more holes in less time to enable completion and production operations to begin. However, unplanned events that introduce unexpected and costly delays often occur during the drilling phase. These unplanned events must be dealt with in a timely and effective manner to enable drilling operations to continue. One event type common to drilling operations is the need to set openhole cement plugs for plug back, kickoff, or curing loss-circulation intervals. The time and cost associated with spotting cement plugs directly impacts well operations and is often classified as nonproductive time (NPT) by operators, especially if initial plugs fail to achieve the purpose for which they were set. Placing cement plugs in today’s complex wellbores and the increased costs associated with these operations necessitates the use of plug designs and procedures that have been designed to reduce risk and utilize new technologies and documented processes to achieve the desired results. Reviewing current practices for deploying new technology helps to optimize overall plug cementing operations in both vertical and extended-reach wellbores. However, there are a number of challenges associated with setting cement plugs in an openhole well. Most importantly, drillpipe can become differentially stuck across a lost-circulation zone, and the plug can become contaminated with the intermixing of the mud, resulting in inadequate isolation or insufficient strength. An innovative tool (Rogers et al. 2004) has been designed to meet the challenges associated with setting cement plugs. The tool connects sacrificial/drillable tubing to the drillpipe and allows an operator to trip into the well and spot the cement plug across the problematic zone. Once cement is placed, the tool is disengaged and the operator trips the drillpipe out of the hole, leaving the cement plug and tubing undisturbed. The sacrificial tubing can be drillable; therefore, the operator can drill through the plug or commence other operations, as required. This paper discusses the challenges operators face when setting cement plugs and how risks and NPT are reduced with this innovative plug-setting process and tool. Well examples are documented from case histories to illustrate the success and lessons learned.
- Europe (1.00)
- Asia (0.68)
- North America > United States > New Mexico (0.29)
- North America > United States > Texas (0.28)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- (3 more...)