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Failure Analysis of String Corrosion and Its Protection during Constructing and Operating Gas Storage Facility in Bedded Salt Deposit
Yuan, Guangjie (PetroChina Co. Ltd.) | Qinghua, Wang (PetroChina Co. Ltd.) | Ruichen, Shen (PetroChina Co. Ltd.) | Yuan, Jinping (PetroChina Co. Ltd.) | Lijun, Lu (PetroChina Co. Ltd.) | Chunmao, Wang
Abstract With more and more salt cavern gas storage under construction, the corrosion problems of leaching string, production string, and production casing require more attention by experts on gas storage. This paper introduces several corrosion phenomena which are encountered during the operation of leaching salt caverns, and natural gas injection and withdrawal. The main corrosion factors are discussed such as brine, air, microbes, components of natural gas, gas injection velocity, operating status and others. The corrosion mechanisms are also analyzed. In order to prevent the corrosion effects a series of measures are applied successfully during different construction phases of the gas storage facility in the Yangtze River Delta, such as oxygen scavenger and biocide, coating protection, annulus protection liquid, cathodic protection. Introduction The two principal types of underground storage sites used in China today are:depleted reservoirs in oil and/or gas fields, and salt formations. Each type has its own physical characteristics (porosity, permeability, retention capability) and economics (site preparation costs, deliverability rates, cycling capability), which govern its suitability to particular applications. Salt formation storage facilities provide very high withdrawal and injection rates compared with their working gas capacity. Base gas requirements are relatively low. To date, a large amount of natural gas storages in the bedded salt deposits are being constructed by PetroChina as a component of the infrastructure necessary to accommodate the gas flow from the West to East pipeline. It is critical to ensure safe gas consumption in the Yangtze River Delta which is the main gas consumption area. Solution mining is the process by which a void or cavity is created in an underground salt formation for storage purposes [1]. This cavity is created by the dissolution of salt when fresh water is injected into the formation under controlled conditions. The resulting brine is displaced out of the developing caverns for further processing or disposal. Solution mining of the cavity is usually achieved by controlled circulation of water through two concentric leaching strings down the wellbore and up again to the surface. The leaching strings include an inter-medium string and a central string, and it can be seen in Fig.1. Solution mining the caverns represents about 25 - 35 % of the investment in gas storage [2]. Taking one to several years to complete, it is a long process which requires large water resources and which produces just as much brine with a salt concentration of 200 - 310 kg/m3, which is used by can be used by the chlorine and sodium chemical industries, or re-injected into the sub-soil, or even pumped into the sea.
- Asia > China (0.69)
- Asia > Middle East > Israel > Mediterranean Sea (0.24)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > Natural gas storage (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
The Safe Operating Life of Isothermal Steel Vessels For Dock Storages of Liquid Ammonia
Basko, E.M. (Melnikov Central Research and Design Institute of Steel Structures Moscow, Russia) | Larionov, V.V. (Melnikov Central Research and Design Institute of Steel Structures Moscow, Russia) | Lazutin, V.N. (Melnikov Central Research and Design Institute of Steel Structures Moscow, Russia)
ABSTRACT The report considers the problems of life evaluation for the steel isothermal vessels intended for storing of liquid ammonia in connection with their operating conditions. It was determined that in the process of long-term service (up to 30 years) the stress-corrosion damages and structural changes of metal and welded joints of the internal vessel filled with liquid ammonia do not take place. Formation and growth of fatigue cracks as a result of cyclic loading caused by change in height of product filling are regarded as the main probable factor of vessel material damageability. The possibility of normative period refinement for periodical inspection of technical state of ammonia storages with emptying of internal vessel from product is shown by the example of operating life calculation of typical isothermal storage of liquid ammonia with a volume of 20,000 m. INTRODUCTION Storing of liquid ammonia in the dock stores is carried out in the steel vertical isothermal storages having a double-wall construction with a volume of 20,000 m3 and more. For majority of such storages built in the seventies-eighties the schedule guideline life expired and therefore the problem consisting in definition of possibility of their further operating life is of high priority. At present decision on prolongation of the operating life of isothermal storages is made on the basis of results of integrated inspection of their technical state which is carried out in accordance with the current rules every 6?10 years. The fixed dates of regular inspections of internal vessel as well as methods and amounts of inspection appointed without considering conditions of vessel loading, predictable types of probable damages of metal structures and data of continuous monitoring realized by traffic department have no proper justification up to present time.
- Materials > Chemicals > Industrial Gases (1.00)
- Energy > Oil & Gas (0.95)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (0.48)
- Reservoir Description and Dynamics (0.48)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (0.48)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (0.34)
Abstract Eni started producing oil reserves from the Aquila reservoir in the Adriatic Sea after the discovery in 1981. As primary production decreased, a decision was made to start enhanced recovery with artificial gas lift. Located in deep waters (815 meters) and 46 km off the southern coast of Italy, a floating production, storage and offloading vessel (FPSO) was needed. As part of the production process scheme, the vessel needed to generate steam and electricity from the produced associated gas. Equipment was installed to remove hydrogen sulfide (H2S) from a combination of the oil stabilizer overhead vapors, the sour water stripper overhead vapors and, if required, a slip stream of the produced gas. The treated gas must meet an H2S specification of 100 parts per million vapor (ppmv) to provide stripping gas for the sour water stripper and meet post combustion emissions specifications from the steam boiler and turbine generator. The anticipated sulfur removal requirement was 2.3 metric tons per day (MTPD). Eni requested a process that would be economical while minimizing environmental impact, operator attention and logistical support. Following a detailed evaluation, the liquid redox process from Merichem Company (Merichem) was selected for the Aquila Phase II Project and installed as part of the topsides on the FPSO Firenze. After a five-year run (2013-2018), the FPSO Firenze has stopped production due to low oil production. This case study looks at the decision to use LO-CAT H2S removal technology (a liquid reduction-oxidation process), the cost of operation, and the unit availability over its' lifetime. Introduction As the energy industry searches for reserves in ever-deeper formations, there appears to be more sulfur with which to contend. Deep oil reservoirs in the Caspian Sea, Gulf of Mexico and offshore Brazil show significant amounts of H2S in the produced well fluids. H2S at low levels (just 100 ppmv) is a life-threatening, corrosive and flammable gas. Exploration and production of fields with significant H2S levels must be done under very strict safety precautions. Ultimately, disposal of the H2S must be designed into the production facilities. Several H2S removal technologies are available, including non-regenerative liquid scavengers (triazine-based), non-regenerative solid-bed absorbents and the regenerative liquid reduction-oxidation (redox) process. These technologies remove sulfur from associated gas streams and do not release them to the environment. The non-regenerative technologies are often referred to as scavengers. Process Evaluation
- North America > United States (0.25)
- North America > Mexico (0.25)
- Europe > Italy (0.25)
- South America > Brazil (0.24)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Health, Safety, Environment & Sustainability > Health > Noise, chemicals, and other workplace hazards (1.00)
- Facilities Design, Construction and Operation > Offshore Facilities and Subsea Systems > Floating production systems (1.00)
ABSTRACT As the West Valley Demonstration Project (WVDP) continues vitrification operation and begins decontamination activities, it is vital to continue to maintain the integrity of the high-level waste tanks and prevent further corrosion that may disrupt the operation. This paper describes the current operational status and some corrosion concerns with corresponding control measure recommendations. INTRODUCTION The only commercial nuclear fuel reprocessing facility ever to operate in the United States is located on approximately 200 acres of the 3,345-acre Western New York Nuclear Service Center (WNYNSC) near West Valley, New York, The WNYNSC is owned by New York State through the New York State Energy Research and Development Authority (NYSERDA). The commercial nuclear fuel reprocessing facility was leased to a private company sad operated from 1966 to 1972 to recover useable uranium and plutonium. Approximately 640 tons of spent nuclear fuel were reprocessed generating about 600,000 gallons of liquid high-level radioactive waste (HLW), The HLW was placed in storage in an underground tank (8D-2) contained within a concrete vault. Tank 8D-1, an identical tank, was used as the spare backup tank. In 1980, the West Valley Demonstration Project (WVDP) Act was signed by the President of the United States to become Public Law 96-368. The Act directs the Department of Energy (DOE) to solidify the HLW stored at the site into a durable, solid form suitable for shipment to a federal repository, clean and close the facilities used; and dispose of the low-level and transuranic wastes collected during Project operations. In 1981 DOE selected West Valley Nuclear Services Company, Inc. (WVNS), a wholly owned subsidiary of Westinghouse Electric Corporation as prime Project contractor. DOE and WVNS assumed operational control of the site in 1982. Within Tank 8D-2, the HLW had separated into two phase a relatively clear liquid and a thick layer of solid sludge. The stabilization of this waste was planned to be conducted in two stages: 1) pretreatment to separate the salts from the radioactive components, and 2) removal of the HLW from 8D-2 and vitrification into a borosilicate glass waste form using a slurry-fed ceramic melter (SFCM). The pretreatment consisted of processing the liquid phase of the waste through an ion-exchange process using zeolite (a synthetic, sodium aluminosilicate mineral) ion-exchange media. The sludge in the bottom of 8D-2 was then mobilized and mixed with water (washed) to dissolve sulfates and other salts. The wash water was then processed through the zeolite ion-exchange system, Pretreatment operations were started in 1988 and completed in 1995 resulting in approximately 20,000 drums of cemented low-level waste (LLW). During the second stage of stabilization the HLW mixture (consisting of the sludge and the zeolite) is removed from Tank 8D-2 and transferred to the Vitrification Facility where glass-forming chemicals are added and the mixture is fed to a 52-to L joule-heated ceramic melter. The melter is then heated to approximately2,0000F (1,093ยบC ) to produce a homogeneous molten waste/glass blend that is cast into 2-foot (0.6 m) diameter by 10-foot (3.0 m) long stainless steel canisters.
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Health, Safety, Environment & Sustainability > Environment (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
ABSTRACT The purpose of this paper is to provide the history and technological developments of liquid epoxy polymer concrete formulated in the United States as a coating for the protection of buried pipelines. Throughout this paper, liquid epoxy polymer concrete refers to one specific product line and is not necessarily representative of all liquid epoxy polymer concrete. This paper will describe how the product is used for both new pipeline construction and for the rehabilitation of existing lines. Technical data will be presented to illustrate the coating's performance characteristics in terms of corrosion and mechanical protection to the steel pipeline. Case histories are included to demonstrate recent experiences with the liquid epoxy polymer concrete. INTRODUCTION Liquid epoxy polymer concrete formulated as a pipeline coating in the United States has an interesting history. During the mid 1980's, one of the world's largest oil companies, in conjunction with one of the world's leading concrete manufacturer's at the time, jointly undertook a research project to develop a tougher concrete product. Today, the product is known as an epoxy based polymer concrete and is a 100 percent solids material that has far exceeded the technical requirement set-out in the original research project. NEW CONSTRUCTION Epoxy Polymer Concrete Casing Insulators The joint venture utilized their newly developed product to mold bars of epoxy polymer concrete to be used as runners on casing insulators. These insulators separated and insulated the carrier pipe from the crossing pipe (pipe within a pipe) when pulled under a road, river, or creek. The uniqueness of these casing insulators was that they contained no metal parts. Once these new insulators were introduced and marketed to the pipeline industry, it was quickly learned that specifying engineers were looking for a better way to perform road and river crossings. Epoxy Polymer Concrete for Bores and Drills As technology evolved, an idea was created to eliminate the casing pipe by simply pulling the carrier pipe under the crossing. The use of most coatings alone, even with an increased thickness of material, was extremely risky, particularly if the terrain soil was slightly rocky. As a result, the casing- less crossings were accomplished by top-coating the pipe with a thick layer of concrete, which acted as a heavy protective layer over the corrosion coating. However, this method caused the pipe to become very heavy and cumbersome to handle. In June 1990, a group of engineers knowledgeable to the pipeline industry purchased the assets of the original joint venture and further developed the technology. They learned that by applying the epoxy polymer concrete directly over a fusion bonded epoxy coated carrier pipe, that they had set-out to address the industry's desire to eliminate the use of high weight coating protectors. Since outstanding results had been attained in the toughness of the epoxy polymer concrete, as well as a high degree of bond to the fusion bonded epoxy, the application of epoxy based polymer concrete over the fusion bonded epoxy was a natural. Listed below are some of the physical properties of epoxy polymer concrete formulated in the United States as a protective mechanical over-coat for F.B.E. coated pipelines. TABLE 1 PHYSICAL PROPERTIES OF LIQUID EPOXY POLYMER CONCRETE Today, more than ten years later, epoxy polymer concrete formulated in the USA as a mechanical overcoat has been specified and successfully used by more engineering firms world-wide than any other product used for similar applications. It continues to offer ultimate protection to fusion
- North America > Canada (0.89)
- Europe > Russia > Northwestern Federal District > Komi Republic > Timan-Pechora Basin > Pechora-Kolva Basin > Usa Field (0.89)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Piping design and simulation (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (0.97)