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This paper provides substantial and compelling evidence from API (American Petroleum Institute) CCS (Carbon Capture & Storage) Work Group and other studies of CO2 EOR (enhanced oil recovery) and CCS projects showing that CO2 capture, transport, and (GS) geologic-sequestration can be a safe and effective method to reduce GHG (greenhouse gas) emissions and mitigate climate change. The paper summarizes how the oil and gas (O&G) industry has achieved great success in engineering the process to capture, transport, and inject CO2 in EOR projects. This success is seen in over 37 years of safe and environmentally friendly large-scale operations, lessons learned, technical advancements, and millions of tons of CO2 injected. Third party investigations to evaluate this successful record are discussed, including some completed ones that have published statements validating the O&G industry's success. Now that CCS is being widely considered and a few countries have begun to implement commercial-scale CCS projects, technology transfer efforts such as this paper are needed to share the experience of the oil and gas industry and the major contribution it can make as part of the solution for climate change. Introduction Historical Overview. Since the first patent for CO2 EOR was granted in 1952 (Whorton), the O&G industry has spent many tens of billions of dollars developing and implementing CO2 EOR technologies, asset development, and operational experience. As new sources of CO2 have become available, field testing and demonstration or pilot project activities have been conducted. These development and improvement efforts have been continuous since the first project in 1964. The first large-scale, commercial CO2 EOR project began operations in 1972 at the SACROC field in West Texas, which continues in operation today. Many more have started since then and by 2008 had reached a total of 112 projects, as reported in the EOR Survey by the Oil and Gas Journal (O&GJ, 2008). Since 1952, numerous patents, best practices, equipment, and products have been developed for CO2 EOR well construction and injection/production operations. Innovative, cost-effective materials, equipment, and methods continue to be developed and implemented such as the recent introduction of real-time, smart-well operations at SACROC. Much of this knowledge has been documented in hundreds of technical papers and several books that have been published on the subject including many applicable API standards and specifications. CO2 EOR Technology for CCS Deployment. Underground geological storage of CO2 is a promising technology for reducing greenhouse gas (GHG) emissions because much of the technology developed by the oil and gas industry associated with natural gas processing and CO2 EOR can support the sound implementation of CCS and huge storage capacity exists in deep saline formations, depleted oil and gas reservoirs, and unmineable coal seams. According to a major report by the Intergovernmental Panel on Climate Change (IPCC, 2005), as much as 55 percent of a worldwide GHG mitigation effort thru 2100 could be achieved through carbon capture and storage. The IPCC also expresses confidence that CO2 can be stored safely over very long periods of time and cites several studies as evidence that the potential for leakage decreases the longer the CO2 is underground.
This paper provides substantial and compelling evidence from API (American Petroleum Institute) CCS (Carbon Capture & Storage) Work Group and other studies of CO2 EOR (enhanced oil recovery) and CCS projects showing that CO2 capture, transport, and (GS) geologic-sequestration can be a safe and effective method to reduce GHG (greenhouse gas) emissions and mitigate climate change. The paper summarizes how the oil and gas (O&G) industry has achieved great success in engineering the process to capture, transport, and inject CO2 in EOR projects. This success is seen in over 37 years of safe and environmentally friendly large-scale operations, lessons learned, technical advancements, and millions of tons of CO2 injected. Third party investigations to evaluate this successful record are discussed, including some completed ones that have published statements validating the O&G industry's success. Now that CCS is being widely considered and a few countries have begun to implement commercial-scale CCS projects, technology transfer efforts such as this paper are needed to share the experience of the oil and gas industry and the major contribution it can make as part of the solution for climate change. Introduction Historical Overview. Since the first patent for CO2 EOR was granted in 1952 (Whorton), the O&G industry has spent many tens of billions of dollars developing and implementing CO2 EOR technologies, asset development, and operational experience. As new sources of CO2 have become available, field testing and demonstration or pilot project activities have been conducted. These development and improvement efforts have been continuous since the first project in 1964. The first large-scale, commercial CO2 EOR project began operations in 1972 at the SACROC field in West Texas, which continues in operation today. Many more have started since then and by 2008 had reached a total of 112 projects, as reported in the EOR Survey by the Oil and Gas Journal (O&GJ, 2008). Since 1952, numerous patents, best practices, equipment, and products have been developed for CO2 EOR well construction and injection/production operations. Innovative, cost-effective materials, equipment, and methods continue to be developed and implemented such as the recent introduction of real-time, smart-well operations at SACROC. Much of this knowledge has been documented in hundreds of technical papers and several books that have been published on the subject including many applicable API standards and specifications. CO2 EOR Technology for CCS Deployment. Underground geological storage of CO2 is a promising technology for reducing greenhouse gas (GHG) emissions because much of the technology developed by the oil and gas industry associated with natural gas processing and CO2 EOR can support the sound implementation of CCS and huge storage capacity exists in deep saline formations, depleted oil and gas reservoirs, and unmineable coal seams. According to a major report by the Intergovernmental Panel on Climate Change (IPCC, 2005), as much as 55 percent of a worldwide GHG mitigation effort thru 2100 could be achieved through carbon capture and storage. The IPCC also expresses confidence that CO2 can be stored safely over very long periods of time and cites several studies as evidence that the potential for leakage decreases the longer the CO2 is underground.
Summary This paper discusses the successful application of a polymer gel during acement squeeze of a depleted zone in a gravel-packed producing well. Theprocess involves proper placement of polymer gel to isolate zones in agravel-pack completion during a cement squeeze. The report also discussesdiagnostic well tests before and after the cement squeeze. The use of polymergel as a blocking agent during a cement squeeze of a gravel-pack completion ofa thermally stimulated well does not appear to be a common practice and has notbeen reported previously. Introduction Squeeze cementing is the process of applying hydraulic pressure to displacea cement slurry into a formation void or a porous zone to obtain a seal betweenthe casing and the formation. Although squeeze cementing has become one of themost common types of downhole remedial jobs, the design and implementation ofsuccessful squeeze jobs for a particular wellbore condition is a subject ofcontinuing research. The successful application of squeeze-cementing technologyrequires an understanding of rock fracturing mechanics, the filtrationproperties of cement slurries pressured against a permeable medium, and theability to control the areal invasion of the cement slurry when it is displacedagainst the formation. Howard and Clark, Binkley et al., Boice and Diller, and Rikediscussed some of the factors to be considered in cementing of casing and theevaluation of squeeze-cementing operations at different wellbore conditions. Because squeeze cementing is usually remedial work, the design and operation ofthe process must be geared toward achieving a particular purpose:preventing unwanted fluid migration into the producing zone, generally referredto as "block squeezing,"stopping excessive water production by squeezingoff the wet zone to eliminate water intrusion,correcting defective primarycementing, andcontrolling high GOR by isolating the oil zone from theadjacent gas zone. Shryock and Slagle discussed some of the problems related tosqueeze cementing. Other reports describe some of the proven methods of oilwellrepairs by cement scab and squeeze cementing in a dolomite reservoir. Bothreports agree with the obvious fact that effective squeeze cementing requiresproper placement of the cement slurry against the zone of interest. The controlof slurry invasion of the formation becomes a critical problem, especially in agravel-pack completion. In this case, the task of squeeze cementing is not onlyto seal off the thief zone, but also to control and prevent cement damage ofthe entire liner. Polymer gel has been used extensively as a diverting agent during acidizing, lost circulation treatments, and primary cementing. Potential applicationsinclude the selective cement squeeze of depleted zones and water-invaded zonesand the repair of casing leaks and damaged liner in gravel-packed completions. Protection of the producing zone is critical during a cement squeeze in agravel-pack completion, and this approach prevents cement invasion of the lowerproducing zone, eliminating the chance of cementing the entire liner completionduring the squeeze job. The favorable economics of the process makesrecompletion of partially depleted wells very attractive compared torecompletion with a liner and gravel-pack completion. The well described in this paper had a well-defined, highly permeable(thief) zone that had previously caused steam channeling during cyclic steamstimulation of the well. The steam-injection profile needed to be correctedpermanently for any hope of success in subsequent steam cycles. After thesqueeze, the producing zone was properly stimulated, and well productionincreased significantly.
Cementing production casing in partially depleted reservoirs is a common problem in the Mid-Continent. The industry is continually looking for alternative slurry designs to lower annular pressures during cementing while maintaining the material properties needed for stimulation and zonal isolation. In order to be viable, the resulting technology must decrease density while preserving compressive strength, fluid loss and free water properties of the cement. Cement slurries using foam or hollow spheres are capable of meeting these requirements. The additional equipment and material cost required usually prevent these systems from being economical when mixed between 13.5 and 14 ppg (lb/gal). Recent technical developments have lead to the creation of slurries weighing 13.8 ppg containing 60% pozzolan and 40% API cement. These economical slurries exhibit mechanical properties comparable to standard API slurries having much higher densities. Laboratory testing and bond logs are presented and compared along with recommended applications. Introduction Formation pressures in producing reservoirs throughout the central United States have steadily declined since production from these reservoirs began. Low formation pressures have created significant challenges for drilling and completion. Many areas have been placed on water flooding programs in an effort to maintain formation pressure. Stage tools and/or low-density slurries are often used to avoid loosing circulation while cementing. Three techniques are commonly utilized for low density cementing:Foam slurries have been used since the early 70's. Initial research was conducted at the Colorado School of Mines as well as several Russian research institutions. While conceptually attractive, the challenges of producing uniform foam cement throughout the desired annular space have been significant. Recent developments in computer control systems have significantly improved the capability to produce uniform foamed cement. This technology and the associated equipment required significantly increases the cost of cementing.The use of lightweight glass or ceramic beads to lower density was introduced in the same time frame as foam cementing. Due to the high cost of these materials, this technology is cost prohibitive for typical slurry volumes in all but the most prolific wells.Fly ash or pozzolan may be used to decrease slurry density due its lower specific gravity compared to cement. Historically, this option has been limited by the degradation of slurry properties when high ratios of pozzolan are used. Recent additive developments have enabled slurries with pozzolan ratios greater than 50% and densities below 14 ppg to achieve mechanical properties comparable to completion slurries with much higher densities. Development Type ‘F’ fly ash is a low-cost and readily available byproduct of coal combustion. Commonly known in oilfield operations as pozzolan or ‘poz’ it is often used as a cement extender. The beneficial properties of pozzolan, a highly reactive silica, combined with cement have been recognized by the construction industry for many years. As lime is liberated during the hydration of cement, it reacts with pozzolan to form calcium silicates and aluminates. These by-products increase the density and decrease the permeability of the set cement slurry contributing to compressive strength development. This reaction also reduces the amount of lime present to react with organic acid, thus producing a more acid resistant cement3,4. The partial replacement of cement with pozzolan reduces the over-all heat of hydration, thereby reducing the propensity to develop thermal cracks at lower temperatures5. Pozzolan has a specific gravity of 2.5 as compared to 3.16 for Portland cement. This density difference results in decreased slurry density in pozzolan blends.
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