《NACE-24198-2006.pdf》由会员分享，可在线阅读，更多相关《NACE-24198-2006.pdf（28页珍藏版）》请在三一文库上搜索。
1、Item No. 24189 NACE International Publication 1F196 This Technical Committee Report has been prepared by NACE International Work Group T-1F-21d* and Task Group T-1F-21* on Corrosion-Resistant Alloys for Use in Oil and Gas Production Survey of CRA Tubular Usage March 1996, NACE International This NAC
2、E International technical committee report represents a consensus of those individual members who have reviewed this document, its scope, and provisions. Its acceptance does not in any respect preclude anyone from manufacturing, marketing, purchasing, or using products, processes, or procedures not
3、included in this report. Nothing contained in this NACE International report is to be construed as granting any right, by implication or otherwise, to manufacture, sell, or use in connection with any method, apparatus, or product covered by Letters Patent, or as indemnifying or protecting anyone aga
4、inst liability for infringement of Letters Patent. This report should in no way be interpreted as a restriction on the use of better procedures or materials not discussed herein. Neither is this report intended to apply in all cases relating to the subject. Unpredictable circumstances may negate the
5、 usefulness of this report in specific instances. NACE International assumes no responsibility for the interpretation or use of this report by other parties. Users of this NACE International report are responsible for reviewing appropriate health, safety, environmental, and regulatory documents and
6、for determining their applicability in relation to this report prior to its use. This NACE International report may not necessarily address all potential health and safety problems or environmental hazards associated with the use of materials, equipment, and/or operations detailed or referred to wit
7、hin this report. Users of this NACE International report are also responsible for establishing appropriate health, safety, and environmental protection practices, in consultation with appropriate regulatory authorities if necessary, to achieve compliance with any existing applicable regulatory requi
8、rements prior to the use of this report. CAUTIONARY NOTICE: The user is cautioned to obtain the latest edition of this report. NACE International reports are subject to periodic review, and may be revised or withdrawn at any time without prior notice. NACE reports are automatically withdrawn if more
9、 than 10 years old. Purchasers of NACE International reports may receive current information on all NACE International publications by contacting the NACE International Membership Services Department, P.O. Box 218340, Houston, Texas 77218-8340 (telephone +1 281228-6200). FOREWORD For two years, NACE
10、 Work Group T-1F-21d solicited data from oil and gas companies on the use of corrosion- resistant-alloy (CRA) tubulars in oil and gas production. The survey was limited to tubing and casing applications to keep the scope of the survey manageable. No attempt was made to include applications involving
11、 downhole, wellhead, or surface equipment. Data were furnished by 12 companies, and it is conservatively estimated that the results of the survey account for 3.6 million meters of pipe, or approximately 70% of CRAs used as casing and tubing in the United States, a fraction of the CRAs in use in the
12、North Sea and Africa, and essentially none on the important applications in the Middle East and Eastern Europe. Therefore, the trends observed in this database may not be pertinent to worldwide applications. In order to obtain accurate information, data were only solicited from oil and gas producers
13、. Surveys compiled from data furnished primarily by CRA manufacturers are generally of questionable accuracy because manufacturers rarely know the actual disposition of pipe after it is shipped. Pipe is frequently diverted to applications significantly different from the applications for which it wa
14、s purchased. Although the work group solicited data on key environmental variables, such as water production, acid- izing, and completion fluids, that could have significant effects on the corrosion resistance and the environmental cracking resistance of CRAs, essentially no data in these categories
15、 were submitted. Furthermore, essentially no data were furnished describing materials problems, field failures, and workovers. Industrys use of CRA tubulars in corrosive oil and gas well environments is quantified in terms of usage rates and environmental variables. Because the survey contains only
16、information that was furnished to the work group, it is recognized that a significant amount of information concerning CRA usage is not included in the database. _ *Chairman Maurice Watkins, Exxon Production Research Co., Houston, TX. *Chairman David Currie, Mobil E therefore, there is insufficient
17、service experience to accurately describe or predict long-term behavior of CRAs. Copyright NACE International Provided by IHS under license with NACELicensee=IHS Employees/1111111001, User=listmgr, listmgr Not for Resale, 03/05/2007 18:12:28 MSTNo reproduction or networking permitted without license
18、 from IHS -,-,- NACE International 6 TABLE 5: QUANTITY (103 m) OF CRAs AT BOTTOMHOLE TEMPERATURE Temperature, C 9Cr 13Cr 22Cr 28 825 G3 2550 G50 C276 Totals 204 4 16 32 57 108 (4) (14) (29) (53) (100) Totals 255 2,529 372 11 67 11 176 38 78 3,538 ( ) = % of total CRAs for a specific temperature rang
19、e. FIGURE 4: PERCENTAGE OF CRAS AT VARIOUS BOTTOMHOLE TEMPERATURES Copyright NACE International Provided by IHS under license with NACELicensee=IHS Employees/1111111001, User=listmgr, listmgr Not for Resale, 03/05/2007 18:12:28 MSTNo reproduction or networking permitted without license from IHS -,-,
20、- NACE International 7 Bottomhole Temperature Figure 4 shows that the highest percentage of pipe was installed in wells with modest bottomhole temperatures. Approximately 47% of CRAs were in wells where the bottomhole temperatures were 121C (250F) or below, while 61% were in wells where the bottomho
21、le temperatures were 149C (300F) or below. Applications with bottomhole temperatures above 177C (350F) only comprised 8% of the total number of CRAs in use. This finding appears to be contradictory to a popular belief in industry that CRAs are primarily used in high-temperature applications. Althoug
22、h the bottomhole temperature is used in the database, it is recognized that there are temperature gradients in wells, and that most joints of the pipe in a well are not exposed to the bottomhole temperature. Moreover, in wells in which the tubing string was composed of different CRAs, each of the di
23、fferent CRAs could not have been exposed to the bottomhole temperature. From the data provided, it was not possible to determine the maximum temperature that each alloy in the mixed string encountered. H2S Concentration Figure 5 shows the distribution of Cr CRAs as a function of H2S concentration. F
24、ifty-nine percent of 9Cr, 13Cr, and 22Cr alloys were in service where there was no H2S, and an additional 22% of these alloys were in environments where the concentration was 10 ppm or less. Thus, more than four- fifths of the reported quantities of the Cr CRAs were being used in environments that c
25、ontained very small concentrations of H2S. One gas field with a H2S concentration of 30 ppm, representing 4% of the total, made up the entire contribution representing concentrations of 10 to 30 ppm. The final 15% of Cr CRAs were in oil wells with H2S concentrations above 100 ppm. FIGURE 5: PERCENTA
26、GE OF CR CRAS AT VARIOUS H2S CONCENTRATIONS H2S Partial Pressure The partial pressure of H2S is approximated by multiplying the mole fraction of H2S in the gas by the bottomhole pressure. The distribution by H2S partial pressure for the Cr CRAs is shown in Figure 6. Sixty percent of Cr CRAs were in
27、environments with H2S partial pressure of zero. It is noted that a total of 68% of Cr CRAs were in environments that had H2S partial pressures of less than 0.3 kPa (0.05 psi), the value that is frequently used to define the onset of sour service. H2S partial pressures greater than 3.4 kPa (0.5 psi),
28、 which were 14% of the total, represented primarily oil well environments. Copyright NACE International Provided by IHS under license with NACELicensee=IHS Employees/1111111001, User=listmgr, listmgr Not for Resale, 03/05/2007 18:12:28 MSTNo reproduction or networking permitted without license from
29、IHS -,-,- NACE International 8 FIGURE 6: PERCENTAGE OF CR CRAS AT VARIOUS H2S PARTIAL PRESSURES The distribution of the highly alloyed CRAs as a function of H2S partial pressures is shown in Figure 7. Approximately 40% of the highly alloyed CRAs were in environments that had H2S partial pressures of
30、 less than 690 kPa (100 psi). In fact, all cases in this range did not exceed 138 kPa (20 psi). The middle partial pressure ranges, 690 to 1,379 kPa (100 to 200 psi) and 1,379 to 2,068 kPa (200 to 300 psi), made up 17% and 28% of the environments of the highly alloyed CRAs, respectively. The highest
31、 range, greater than 2,068 kPa (300 psi), comprised approximately 15% of the total and represented primarily H2S partial pressures above 6,205 kPa (900 psi). Carbon Dioxide Concentration Figure 8 shows that the Cr CRAs were distributed over a wide range of concentrations of carbon dioxide (CO2). The
32、 greater-than-15% CO2 pie section in Figure 8 includes concentrations that were 100% CO2. The use of highly alloyed CRAs was not analyzed in terms of CO2 concentration because it does not typically influence the selection of highly alloyed CRAs. TRENDS IN Cr CRA USAGE 9Cr (UNS S50400) In general, mo
33、st 9Cr was installed in gas wells that contained either very small concentrations of or no H2S. Approximately 171,907 m (564,000 ft) or 67% of 9Cr tubulars were in environments where the H2S concentration was reported as 0 ppm. For gas wells, the highest reported H2S concentration was 2 ppm, which c
34、orresponds to a H2S partial pressure of 0.21 kPa (0.03 psi). Higher H2S partial pressures of 0.28 and 5.2 kPa (0.04 and 0.75 psi) were reported for oil wells in the North Sea. These partial pressures corresponded to H2S concentrations of 10 and 300 ppm, respectively. With one exception, the bottomho
35、le temperatures for 9Cr were below 121C (250F). One well had a bottom-hole temperature of 177C (350F) and a H2S partial pressure of 0.07 kPa (0.01 psi). Table 4 shows that 92% of 9Cr tubulars were installed between 1985 and 1989, most of which were in gas wells that contained very large amounts of C
36、O2. 13Cr (UNS S42000) Figure 2 shows that 13Cr has been the most-used CRA, particularly in recent years. Of the 2,563,338 m (8,409,900 ft) of 13Cr reported in the database, approximately 1,062,145 m (1,939,000 ft) (43%) were installed during the period 1990 to 1993, and another 688,985 m (2,260,450
37、ft) (28%) were installed during the period 1985 to 1989. Copyright NACE International Provided by IHS under license with NACELicensee=IHS Employees/1111111001, User=listmgr, listmgr Not for Resale, 03/05/2007 18:12:28 MSTNo reproduction or networking permitted without license from IHS -,-,- NACE Int
38、ernational 9 FIGURE 7: PERCENTAGE OF HIGHLY ALLOYED CRAS FOR VARIOUS H2S PARTIAL PRESSURES FIGURE 8: PERCENTAGE OF CR CRAS AT VARIOUS CO2 CONCENTRATIONS Copyright NACE International Provided by IHS under license with NACELicensee=IHS Employees/1111111001, User=listmgr, listmgr Not for Resale, 03/05/
39、2007 18:12:28 MSTNo reproduction or networking permitted without license from IHS -,-,- NACE International 10 Table 5 shows that 1,031,000 m (3,382,000 ft) of 13Cr tubulars were in service in environments where the bottomhole temperatures were between 93 and 121C (200 and 250F). Table 6 shows that t
40、his quantity is 41% of the 13Cr tubulars in the database. Table 5 also shows that 13Cr tubulars accounted for 82% of all CRA tubulars in this temperature range. Similarly, 62% of 13Cr tubulars were in service where the bottomhole temperatures were less than 149C (300F). Thirty-nine percent of 13Cr,
41、approximately 974,000 m (3,197,000 ft), were in service in environments where the bottomhole temperatures were in the range of 149 to 177C (300 to 350F). TABLE 6: % CRAs AT VARIOUS TEMPERATURES Temperature, C 9Cr 13Cr 22Cr 28 825 G3 2550 G50 C276 Totals 204 35 9 83 72 3 Totals 100 100 100 100 100 10
42、0 100 100 100 100 Like 9Cr, most 13Cr tubulars have been installed in environments containing very small amounts of H2S. Approximately 1,653,000 m (5,437,500 ft) of 13Cr tubulars were in environments where the H2S concentration was zero. Table 7 shows that 13Cr tubulars comprised 88% of the Cr CRAs
43、in service at a H2S concentration equal to 0 ppm. Table 8 shows that 64% of 13Cr tubulars were in environments that contained 0 ppm H2S. Moreover, 78% of 13Cr tubulars were in environments where the H2S concentration was less than 10 ppm (Table 8) and 73% were at partial pressures less than 0.34 kPa
44、 (0.05 psi). TABLE 7: QUANTITY (103 M) OF CR CRAS AT VARIOUS H2S CONCENTRATIONS H2S Concentration, ppm 9Cr 13Cr 22Cr Totals 0 172 1,653 52 1,709 (9) (88) (10) (100) 1-10 50 356 301 2,319 (7) (50) (43) (100) 10-30 122 400 (100) (100) 30 34 433 18 1,589 (7) (89) (4) (100) Totals 255 2,563 372 3,190 (
45、) = % of total CRAs at H2S concentration. The highest H2S concentration reported for a gas well was 30 ppm, which corresponds to a partial pressure of 3.31 kPa (0.48 psi). At 160C (320F), this particular application also had one of the highest reported bottom- hole temperatures for 13Cr. The highest
46、 bottomhole temperature for 13Cr in the database is 177C (350F); the highest H2S partial pressure at this temperature is 0.55 kPa (0.08 psi), which corresponds to a H2S concentration of 6 ppm. The highest concentrations and partial pressures of H2S that are shown in Figures 10 and 11 and Tables 7 th
47、rough 10 were reported in oil wells in Alaska and the North Sea. These wells accounted for usage of 36% of 13Cr tubulars. The bottomhole temperatures were 104C (220F) and 93C (200F), respectively. Copyright NACE International Provided by IHS under license with NACELicensee=IHS Employees/1111111001,
48、User=listmgr, listmgr Not for Resale, 03/05/2007 18:12:28 MSTNo reproduction or networking permitted without license from IHS -,-,- NACE International 11 13Cr tubulars were distributed over the entire range of CO2 concentrations. TABLE 8: % Cr CRAs AT VARIOUS H2S CONCENTRATIONS H2S Concentration, ppm 9Cr 13Cr 22Cr Totals 0 67 64 14 59 1-10 20 14 81 22 10-30 5 4 30 13 17 5 15 Totals 100 100 100 100 22Cr (UNS S31803) Similar to that of 13Cr tubulars, the quantity of 22Cr tubulars increased significantly between 1975 and 1989. During the period 1980 to 1984, 137,000 m