{"title":"Case Study: Sand Separation in Surface Facilities for Heavy and Extra Heavy Oil","authors":"P. Boschee","doi":"10.2118/1014-0025-OGF","DOIUrl":"https://doi.org/10.2118/1014-0025-OGF","url":null,"abstract":"","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"21 1","pages":"25-29"},"PeriodicalIF":0.0,"publicationDate":"2014-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74772648","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"Optimization Study of a Novel Water-Ionic Technology for Smart-Waterflooding Application in Carbonate Reservoirs","authors":"A. Yousef, S. Ayirala","doi":"10.2118/169052-PA","DOIUrl":"https://doi.org/10.2118/169052-PA","url":null,"abstract":"","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"44 1","pages":"72-82"},"PeriodicalIF":0.0,"publicationDate":"2014-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74995196","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"Taking a Closer Look at Why Projects Fail","authors":"S. Whitfield","doi":"10.2118/1014-0018-OGF","DOIUrl":"https://doi.org/10.2118/1014-0018-OGF","url":null,"abstract":"","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"3 1","pages":"18-24"},"PeriodicalIF":0.0,"publicationDate":"2014-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77770668","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"Barzan Onshore-Gas-Facilities Construction: Attaining Excellence Through a Comprehensive SHE&S Management System","authors":"Robert E. DeHart, J. Brand","doi":"10.2118/172504-PA","DOIUrl":"https://doi.org/10.2118/172504-PA","url":null,"abstract":"","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"1 1","pages":"53-65"},"PeriodicalIF":0.0,"publicationDate":"2014-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82839499","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Summary Process-control engineering is a fairly narrow field of study that has used inconsistent terminology among practitioners. Naturalgas-actuated pneumatic-control equipment has recently become a focus area for regulators trying to reduce the quantity of actual pollutants and greenhouse gases released to the atmosphere. The historical use of inconsistent key terms by experts has led to regulations that are at odds with the realities of existing equipment. The intention of this paper is to begin development of a rigorous set of terms and operational classifications that can help create a framework of knowledge consistent with how this equipment functions. Standardization of terminology has benefits for operators, manufacturers, and regulators alike.
{"title":"Pneumatic Controllers in Upstream Oil and Gas","authors":"David A. Simpson","doi":"10.2118/172505-PA","DOIUrl":"https://doi.org/10.2118/172505-PA","url":null,"abstract":"Summary Process-control engineering is a fairly narrow field of study that has used inconsistent terminology among practitioners. Naturalgas-actuated pneumatic-control equipment has recently become a focus area for regulators trying to reduce the quantity of actual pollutants and greenhouse gases released to the atmosphere. The historical use of inconsistent key terms by experts has led to regulations that are at odds with the realities of existing equipment. The intention of this paper is to begin development of a rigorous set of terms and operational classifications that can help create a framework of knowledge consistent with how this equipment functions. Standardization of terminology has benefits for operators, manufacturers, and regulators alike.","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"25 1","pages":"83-96"},"PeriodicalIF":0.0,"publicationDate":"2014-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81422756","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"Commissioning: Making the Connection Between Construction and Operations","authors":"W. Furlow","doi":"10.2118/1014-0033-OGF","DOIUrl":"https://doi.org/10.2118/1014-0033-OGF","url":null,"abstract":"","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"3 1","pages":"33-34"},"PeriodicalIF":0.0,"publicationDate":"2014-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75276899","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Summary The Huizhou oil field is located at the Pearl River mouth in the continental-shelf region of the South China Sea, with an average water depth of approximately 117 m. The oil field’s main facilities include eight fixed-jacket platforms, two subsea-production wellheads (HZ32-5 and HZ26-1N), and one floating production, storage, and offloading (FPSO) vessel (Nanhai Faxian). Fig. 1 illustrates the general layout of the field. The peak daily oil production is approximately 70,000 BOPD. In September 2009, after a strong typhoon (Koppu) passed over this oil field, the FPSO vessel’s permanent mooring system was seriously damaged. All production risers connected to the FPSO vessel’s turret were ruptured, and production was forced to shut down. To resume production in a fast-track manner, several engineering cases were studied. Finally, the concept of using a dynamic-positioning (DP) FPSO vessel to temporarily resume production was selected. Detailed design and operability analysis was performed by the owner of the DP-FPSO vessel, and various flexible pipes and other materials were sourced quickly in local and international markets. The offshore installation took place throughout the harsh winter monsoonal season from November 2009 to February 2010. Finally, the field was brought back into production after 5.5 months of production stoppage. The DPFPSO system operated for more than 18 months and proved safe and effective. This was a world record time for an FPSO vessel operated in DP mode.
{"title":"Fast Production Recovery of a Typhoon-Damaged Oil Field in the South China Sea","authors":"Mao Jiayou","doi":"10.2118/172999-PA","DOIUrl":"https://doi.org/10.2118/172999-PA","url":null,"abstract":"Summary The Huizhou oil field is located at the Pearl River mouth in the continental-shelf region of the South China Sea, with an average water depth of approximately 117 m. The oil field’s main facilities include eight fixed-jacket platforms, two subsea-production wellheads (HZ32-5 and HZ26-1N), and one floating production, storage, and offloading (FPSO) vessel (Nanhai Faxian). Fig. 1 illustrates the general layout of the field. The peak daily oil production is approximately 70,000 BOPD. In September 2009, after a strong typhoon (Koppu) passed over this oil field, the FPSO vessel’s permanent mooring system was seriously damaged. All production risers connected to the FPSO vessel’s turret were ruptured, and production was forced to shut down. To resume production in a fast-track manner, several engineering cases were studied. Finally, the concept of using a dynamic-positioning (DP) FPSO vessel to temporarily resume production was selected. Detailed design and operability analysis was performed by the owner of the DP-FPSO vessel, and various flexible pipes and other materials were sourced quickly in local and international markets. The offshore installation took place throughout the harsh winter monsoonal season from November 2009 to February 2010. Finally, the field was brought back into production after 5.5 months of production stoppage. The DPFPSO system operated for more than 18 months and proved safe and effective. This was a world record time for an FPSO vessel operated in DP mode.","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"373 1","pages":"66-71"},"PeriodicalIF":0.0,"publicationDate":"2014-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86884798","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Kegang Ling, Guoqing Han, Xiao Ni, Chunming Xu, Jun He, P. Pei, J. Ge
lower cost. It also has the advantages of monitoring the system continuously and noninterference with pipeline operations. One of the limitations of the modeling method is that it requires flow parameters, which are not always available. Leak detection from mathematical modeling also has a higher uncertainty than that from physical inspection. Many researchers have conducted investigations on gas transient flow in pipelines to detect leaks. Huber (1981) used a computerbased pipeline simulator for batch tracking, line balance, and leak detection in the Cochin pipeline system. The instruments installed in the pipeline and the simulator in the central control office made online, real-time surveillance of the line possible. The resulting model was capable of determining pressure, temperature, density, and flow profiles for the line. The simulator was based on mass balance, and thus required a complete set of variables to detect the leak. Shell used physical methods to detect leaks in a 36-in.-diameter, 78-mile-long submarine pipeline near Bintulu, Sarawak (van der Marel and Sluyter 1984). The leaks were detected accurately by optical and acoustical equipment mounted on a remotely operated vehicle, which was guided along the pipeline from a distance of 0.5 m above the pipeline. The disadvantages of this detection method are time consumption (15 days to finish detection), and the pipeline needed to be kept at a high pressure to obtain a relatively high signal/noise ratio. Sections of the pipeline were covered by a thick layer of selected backfill. This ruled out the use of the optical technology. It is also noted that the maximum water depth was 230 ft. Applications in a deepwater environment have not been tested. Luongo (1986) studied the gas transient flow in a constantcross-section pipe. He linearized the partial-differential equation and developed a numerical solution to the linear parabolic partialdifferential equation. In his derivation, friction factor was calculated from steady-state conditions (i.e., constant friction factor for transient flow). Luongo (1986) claimed that his linearization algorithm can save 25% in the computational time without a major sacrifice in accuracy when compared with other methods. The governing equations used by Luongo (1986) required a complete data set of pressure and flow rate. Massinon (1988) proposed a real-time transient hydraulic model for leak detection and batch tracking on a liquid-pipeline system on the basis of the conservation of mass, momentum, and energy, and an equation of state. Although this model can detect leaks in a timely manner, it required intensive acquisition of complete data sets, both in the space domain (the pipeline lengths between sensors are very short) and in the time domain (time interval between two consecutive measurements is short), which are impossible for many pipelines. Mactaggart (1989) applied a compensated volume-balance method at a cost less than a transient-model-based le
{"title":"A New Method for Leak Detection in Gas Pipelines","authors":"Kegang Ling, Guoqing Han, Xiao Ni, Chunming Xu, Jun He, P. Pei, J. Ge","doi":"10.2118/2014-1891568-PA","DOIUrl":"https://doi.org/10.2118/2014-1891568-PA","url":null,"abstract":"lower cost. It also has the advantages of monitoring the system continuously and noninterference with pipeline operations. One of the limitations of the modeling method is that it requires flow parameters, which are not always available. Leak detection from mathematical modeling also has a higher uncertainty than that from physical inspection. Many researchers have conducted investigations on gas transient flow in pipelines to detect leaks. Huber (1981) used a computerbased pipeline simulator for batch tracking, line balance, and leak detection in the Cochin pipeline system. The instruments installed in the pipeline and the simulator in the central control office made online, real-time surveillance of the line possible. The resulting model was capable of determining pressure, temperature, density, and flow profiles for the line. The simulator was based on mass balance, and thus required a complete set of variables to detect the leak. Shell used physical methods to detect leaks in a 36-in.-diameter, 78-mile-long submarine pipeline near Bintulu, Sarawak (van der Marel and Sluyter 1984). The leaks were detected accurately by optical and acoustical equipment mounted on a remotely operated vehicle, which was guided along the pipeline from a distance of 0.5 m above the pipeline. The disadvantages of this detection method are time consumption (15 days to finish detection), and the pipeline needed to be kept at a high pressure to obtain a relatively high signal/noise ratio. Sections of the pipeline were covered by a thick layer of selected backfill. This ruled out the use of the optical technology. It is also noted that the maximum water depth was 230 ft. Applications in a deepwater environment have not been tested. Luongo (1986) studied the gas transient flow in a constantcross-section pipe. He linearized the partial-differential equation and developed a numerical solution to the linear parabolic partialdifferential equation. In his derivation, friction factor was calculated from steady-state conditions (i.e., constant friction factor for transient flow). Luongo (1986) claimed that his linearization algorithm can save 25% in the computational time without a major sacrifice in accuracy when compared with other methods. The governing equations used by Luongo (1986) required a complete data set of pressure and flow rate. Massinon (1988) proposed a real-time transient hydraulic model for leak detection and batch tracking on a liquid-pipeline system on the basis of the conservation of mass, momentum, and energy, and an equation of state. Although this model can detect leaks in a timely manner, it required intensive acquisition of complete data sets, both in the space domain (the pipeline lengths between sensors are very short) and in the time domain (time interval between two consecutive measurements is short), which are impossible for many pipelines. Mactaggart (1989) applied a compensated volume-balance method at a cost less than a transient-model-based le","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"56 1","pages":"97-106"},"PeriodicalIF":0.0,"publicationDate":"2014-08-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86204883","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"Case Study: Repsol Shows the Way To Conserve Ecuador’s Amazon","authors":"W. Furlow","doi":"10.2118/0814-0032-OGF","DOIUrl":"https://doi.org/10.2118/0814-0032-OGF","url":null,"abstract":"","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"31 1","pages":"32-34"},"PeriodicalIF":0.0,"publicationDate":"2014-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84600715","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
T. Hayes, Brent Halldorson, P. Horner, J. Ewing, James R. Werline, B. F. Severin
Summary Used extensively by the food, chemical, and pharmaceutical industries, the mechanical-vapor-recompression (MVR) process is viewed as a reliable method for recovering demineralized water from concentrated brines. Devon Energy has supported the operation of an advanced MVR system at a north-central Texas (Barnett shale region) treatment facility. At this facility, pretreatment included caustic addition and clarification for total-suspended-solids and iron control. Pretreated shale-gas flowback water was then sent to three MVR units, each rated at 2,000–2,500 B/D (318–398 m3/d). Data were collected during a 60-day period in the summer of 2010. Distilled-water recovery volume averaged 72.5% of the influent water to the MVR units. The influent total dissolved solids (TDS) fed to the MVR units averaged just under 50 000 mg/L. More than 99% of the TDS were captured in the concentrate stream. The fate of multivalent cations; total petroleum hydrocarbons (TPH); and benzene, toluene, ethylbenzene, and xylenes (BTEX) throughout the treatment system was determined. Most of the iron and TPH removal (90 and 84%, respectively) occurred during pretreatment. The total removal of iron, magnesium, calcium, barium, and boron from the distillate exceeded 99%. BTEX removal from the distillate exceeded 95%. Electric power at the facility was provided by two natural-gas generators, and compressors associated with the MVR units were driven by natural-gas-fueled internal-combustion engines. Energy requirements at the entire treatment facility were tracked daily by total natural-gas use. Best-fit correlations between treated water and distillate production vs. total plant use of natural gas indicated that there was a base power load throughout the facility of approximately 120 to 140 Mscf/D (3400 to 3960 m3/d) of gas. Approximately 48 scf natural gas/bbl influent water treated (270 m3/m3 influent) or 60.5 scf/bbl distillate produced (340 m3/m3 distillate) was required; this represents an energy cost of less than USD 0.25/bbl treated (USD 0.04/m3 treated) and approximately USD 0.30/bbl of distillate product generated (USD 0.048/m3 distillate), assuming a natural-gas cost of USD 5/million Btu (USD 4.72/GJ). Performance in terms of water recovery and product-water quality was stable throughout the 60-day test.
{"title":"Mechanical Vapor Recompression for the Treatment of Shale-Gas Flowback Water","authors":"T. Hayes, Brent Halldorson, P. Horner, J. Ewing, James R. Werline, B. F. Severin","doi":"10.2118/170247-PA","DOIUrl":"https://doi.org/10.2118/170247-PA","url":null,"abstract":"Summary Used extensively by the food, chemical, and pharmaceutical industries, the mechanical-vapor-recompression (MVR) process is viewed as a reliable method for recovering demineralized water from concentrated brines. Devon Energy has supported the operation of an advanced MVR system at a north-central Texas (Barnett shale region) treatment facility. At this facility, pretreatment included caustic addition and clarification for total-suspended-solids and iron control. Pretreated shale-gas flowback water was then sent to three MVR units, each rated at 2,000–2,500 B/D (318–398 m3/d). Data were collected during a 60-day period in the summer of 2010. Distilled-water recovery volume averaged 72.5% of the influent water to the MVR units. The influent total dissolved solids (TDS) fed to the MVR units averaged just under 50 000 mg/L. More than 99% of the TDS were captured in the concentrate stream. The fate of multivalent cations; total petroleum hydrocarbons (TPH); and benzene, toluene, ethylbenzene, and xylenes (BTEX) throughout the treatment system was determined. Most of the iron and TPH removal (90 and 84%, respectively) occurred during pretreatment. The total removal of iron, magnesium, calcium, barium, and boron from the distillate exceeded 99%. BTEX removal from the distillate exceeded 95%. Electric power at the facility was provided by two natural-gas generators, and compressors associated with the MVR units were driven by natural-gas-fueled internal-combustion engines. Energy requirements at the entire treatment facility were tracked daily by total natural-gas use. Best-fit correlations between treated water and distillate production vs. total plant use of natural gas indicated that there was a base power load throughout the facility of approximately 120 to 140 Mscf/D (3400 to 3960 m3/d) of gas. Approximately 48 scf natural gas/bbl influent water treated (270 m3/m3 influent) or 60.5 scf/bbl distillate produced (340 m3/m3 distillate) was required; this represents an energy cost of less than USD 0.25/bbl treated (USD 0.04/m3 treated) and approximately USD 0.30/bbl of distillate product generated (USD 0.048/m3 distillate), assuming a natural-gas cost of USD 5/million Btu (USD 4.72/GJ). Performance in terms of water recovery and product-water quality was stable throughout the 60-day test.","PeriodicalId":19446,"journal":{"name":"Oil and gas facilities","volume":"1217 1","pages":"54-62"},"PeriodicalIF":0.0,"publicationDate":"2014-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87198985","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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