Lost circulation will be a heavy drawback throughout the drilling of an oil well or gas well. Existing mitigation depend for the most part on particulates, which regularly are added to drilling fluids to plug fractures and to develop mud cake to fix drilling fluid losses. Evaluation and testing of LCM in the laboratory before field applications are crucial, Laboratory study was undertaken to compare the performance of conventional lost circulation materials (Mica and Calcium Carbonate) with Palm Kernel Shells and Banana Trunk Fiber as a new blend of lost circulation materials in varying proportions using synthetic based drilling mud. Palm kernel Shells and Banana Trunk Fiber were prepared and sieved to obtain coarse, medium and fine particles which were analyzed in the laboratory to determine Mud density, Particle Size Distribution, Rheological Properties, Permeability plugging efficiency and Acid Solubility using Mud balance, Sieve Analysis, 45-Fann Viscometer, Permeability Plugging Apparatus (PPA) and Acidic Reagents (Hydrochloric and Formic Acid) respectively. The tests were performed to simulate downhole conditions, it was seen that a 2:1 blend of Palm Kernel Shell-Coarse and Banana Trunk Fiber-Medium passes API acceptability test for API acceptable range of plastic viscosity and yield point, but the fine size grades performed poorly. Also, the 2:1 blend of Palm Kernel Shell-Coarse and Banana Trunk Fiber-Medium outperformed the 2:1 blend of Calcium Carbonate-Coarse and Mica-Medium in the synthetic based drilling mud tested. The plugging capacity of the blended mixture of the LCM were tested using a permeability plugging apparatus, the result shows that the sealing efficiency is highly dependent on the fracture width and particle size distribution. Palm Kernel Shells alone were not able to plug the tapered slot and hence the Plug Breaking Pressure (PBP) was zero. The test was carried out at an operating pressure of 3000psi and 200?. It was also observed that the total fluid loss of the 2:1 blended mixture of Palm Kernel Shells and Banana Trunk Fiber is low when compared to same blend of Calcium carbonate and Mica which implies that the former has high ability to form semi permeable filter cake that will seal off depleted intervals and help prevent differential sticking than the latter. Acid Solubility in a reservoir or production zone is important, LCM used in these zones must be removed to permit maximum formation production, when tested with hydrochloric and formic acids, Palm Kernel Shells and Banana Trunk Fiber are both degradable in both 10% of Hydrochloric and 10% Formic acid. Hence, the blended mixture of Palm Kernel Shells and Banana Trunk Fiber is a suitable substitute for conventional LCM. This work confirms that all LCM are not equal, and that the LCM type plays a role in terms of both plugging and "toughness" that better withstands displacement pressures. It also validates that LCM combinations function more efficiently than u
{"title":"Laboratory Study of Oil Palm Kernel Shells and Mangrove Plant Fiber Banana Trunk Fiber as Lost Circulation Materials in Synthetic Based Drilling Mud","authors":"Ekeoma Isaac Prince, A. Dosunmu, C. Anyanwu","doi":"10.2118/198733-MS","DOIUrl":"https://doi.org/10.2118/198733-MS","url":null,"abstract":"\u0000 Lost circulation will be a heavy drawback throughout the drilling of an oil well or gas well. Existing mitigation depend for the most part on particulates, which regularly are added to drilling fluids to plug fractures and to develop mud cake to fix drilling fluid losses.\u0000 Evaluation and testing of LCM in the laboratory before field applications are crucial, Laboratory study was undertaken to compare the performance of conventional lost circulation materials (Mica and Calcium Carbonate) with Palm Kernel Shells and Banana Trunk Fiber as a new blend of lost circulation materials in varying proportions using synthetic based drilling mud. Palm kernel Shells and Banana Trunk Fiber were prepared and sieved to obtain coarse, medium and fine particles which were analyzed in the laboratory to determine Mud density, Particle Size Distribution, Rheological Properties, Permeability plugging efficiency and Acid Solubility using Mud balance, Sieve Analysis, 45-Fann Viscometer, Permeability Plugging Apparatus (PPA) and Acidic Reagents (Hydrochloric and Formic Acid) respectively.\u0000 The tests were performed to simulate downhole conditions, it was seen that a 2:1 blend of Palm Kernel Shell-Coarse and Banana Trunk Fiber-Medium passes API acceptability test for API acceptable range of plastic viscosity and yield point, but the fine size grades performed poorly. Also, the 2:1 blend of Palm Kernel Shell-Coarse and Banana Trunk Fiber-Medium outperformed the 2:1 blend of Calcium Carbonate-Coarse and Mica-Medium in the synthetic based drilling mud tested. The plugging capacity of the blended mixture of the LCM were tested using a permeability plugging apparatus, the result shows that the sealing efficiency is highly dependent on the fracture width and particle size distribution. Palm Kernel Shells alone were not able to plug the tapered slot and hence the Plug Breaking Pressure (PBP) was zero. The test was carried out at an operating pressure of 3000psi and 200?. It was also observed that the total fluid loss of the 2:1 blended mixture of Palm Kernel Shells and Banana Trunk Fiber is low when compared to same blend of Calcium carbonate and Mica which implies that the former has high ability to form semi permeable filter cake that will seal off depleted intervals and help prevent differential sticking than the latter. Acid Solubility in a reservoir or production zone is important, LCM used in these zones must be removed to permit maximum formation production, when tested with hydrochloric and formic acids, Palm Kernel Shells and Banana Trunk Fiber are both degradable in both 10% of Hydrochloric and 10% Formic acid. Hence, the blended mixture of Palm Kernel Shells and Banana Trunk Fiber is a suitable substitute for conventional LCM.\u0000 This work confirms that all LCM are not equal, and that the LCM type plays a role in terms of both plugging and \"toughness\" that better withstands displacement pressures. It also validates that LCM combinations function more efficiently than u","PeriodicalId":11250,"journal":{"name":"Day 3 Wed, August 07, 2019","volume":"21 3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-08-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76957637","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}
Production from gas wells could be very challenging and can lead to spontaneous shutting down of wells for reasons other than known equipment or operational. Some of these wells shut in, not because of surface or sub surface pressure safety settings, but due to Joule Thompson effect. The case study well in this paper is producing but shuts down frequently. The main aim of studying this well is because it is the fuel gas source to the flow station. It is used to run the instruments and the turbine generators, hence production sustainability of the wells in this field depends on the well. This became even more crucial when the well began to shut down frequently, without an immediate known cause. A temperature-sensitive production performance model was developed to mimic the well's performance from the gas reservoir for various surface bean sizes. It was then compared with the thermodynamic model of the well's tubing head and flow line conditions and optimized production rule was made subject to the flow assurance and reservoir management requirements. Chemical hydrate inhibition program was found not to be of immediate necessity after the optimization modeling, hence well was produced by increasing choke size to increase the flow line pressure. This resulted to increase in the flow line temperature and the well was then produced at the non-hydrate formation region of the thermodynamic profile. A stable and uninterrupted production was then achieved with choke increase. Frequent choke erosion as well as the Joule Thompson effect was eliminated by the choke increase. Cost of injection of chemical hydrate inhibitor (methanol) was then saved. Well production of about 800 BOEPD was also restored even with an optimum reservoir performance outside sustaining flow for other wells in the field (4,000 BOPD).
{"title":"Gas Production Optimization Using Thermodynamics Hydrate Inhibition Flow Assurance Method","authors":"K. Nwankwo","doi":"10.2118/198842-MS","DOIUrl":"https://doi.org/10.2118/198842-MS","url":null,"abstract":"\u0000 Production from gas wells could be very challenging and can lead to spontaneous shutting down of wells for reasons other than known equipment or operational. Some of these wells shut in, not because of surface or sub surface pressure safety settings, but due to Joule Thompson effect. The case study well in this paper is producing but shuts down frequently.\u0000 The main aim of studying this well is because it is the fuel gas source to the flow station. It is used to run the instruments and the turbine generators, hence production sustainability of the wells in this field depends on the well. This became even more crucial when the well began to shut down frequently, without an immediate known cause.\u0000 A temperature-sensitive production performance model was developed to mimic the well's performance from the gas reservoir for various surface bean sizes. It was then compared with the thermodynamic model of the well's tubing head and flow line conditions and optimized production rule was made subject to the flow assurance and reservoir management requirements.\u0000 Chemical hydrate inhibition program was found not to be of immediate necessity after the optimization modeling, hence well was produced by increasing choke size to increase the flow line pressure. This resulted to increase in the flow line temperature and the well was then produced at the non-hydrate formation region of the thermodynamic profile.\u0000 A stable and uninterrupted production was then achieved with choke increase. Frequent choke erosion as well as the Joule Thompson effect was eliminated by the choke increase. Cost of injection of chemical hydrate inhibitor (methanol) was then saved. Well production of about 800 BOEPD was also restored even with an optimum reservoir performance outside sustaining flow for other wells in the field (4,000 BOPD).","PeriodicalId":11250,"journal":{"name":"Day 3 Wed, August 07, 2019","volume":"17 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-08-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89585600","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}
Polymers are known for controlling fluid loss and modifying rheology in drilling muds through polymer chain entanglement and polymer-solvent interactions. Natural polymers have been used in the formulation of drilling muds, mainly due to their high molecular weight and eco-friendliness but they have limitations in controlling fluid loss, modifying viscosity or forming good gel strength in saline and thermal environments. This study reports laboratory evaluation of Terminalia mantaly exudates as viscosifier in drilling mud formulations. The effects of polymer concentrations, temperature, pH and salinity on the rheological properties of this novel biopolymer were investigated. Results obtained show that as polymer concentration increases (0.5% – 2.5%w/v), the rheological properties (apparent viscosity, plastic viscosity and yield point) of the biopolymer increased. At the polymer concentrations investigated, an increase in temperature (80°F-150°F) results in a slight decrease in the rheological properties of the polymer. At 2%w/v polymer concentration, an increase in salinity results in a slight decrease in its rheological properties, while at 1.5%w/v polymer concentration, an increase in pH (4-10) shows no significant change in the rheological properties. The shear stress increases with increase in shear rate and obeys the Bingham plastic model. The results obtained show that the polymer has a good alkaline resistance at pH above 7 and stable rheological properties at increased salinity and temperature. This has been attributed to the stable repulsive forces of the negatively charged polyelectrolyte of the polymer as salinity increases. From the results obtained in this study, Terminalia mantaly exudate can be a substitute for conventional natural polymers in water-based drilling muds.
{"title":"Rheological Properties of Terminalia Mantaly Exudate as Drilling Mud Additive","authors":"O. Inemugha, F. Chukwuma, O. Akaranta, J. Ajienka","doi":"10.2118/198827-MS","DOIUrl":"https://doi.org/10.2118/198827-MS","url":null,"abstract":"\u0000 Polymers are known for controlling fluid loss and modifying rheology in drilling muds through polymer chain entanglement and polymer-solvent interactions. Natural polymers have been used in the formulation of drilling muds, mainly due to their high molecular weight and eco-friendliness but they have limitations in controlling fluid loss, modifying viscosity or forming good gel strength in saline and thermal environments. This study reports laboratory evaluation of Terminalia mantaly exudates as viscosifier in drilling mud formulations. The effects of polymer concentrations, temperature, pH and salinity on the rheological properties of this novel biopolymer were investigated. Results obtained show that as polymer concentration increases (0.5% – 2.5%w/v), the rheological properties (apparent viscosity, plastic viscosity and yield point) of the biopolymer increased. At the polymer concentrations investigated, an increase in temperature (80°F-150°F) results in a slight decrease in the rheological properties of the polymer. At 2%w/v polymer concentration, an increase in salinity results in a slight decrease in its rheological properties, while at 1.5%w/v polymer concentration, an increase in pH (4-10) shows no significant change in the rheological properties. The shear stress increases with increase in shear rate and obeys the Bingham plastic model. The results obtained show that the polymer has a good alkaline resistance at pH above 7 and stable rheological properties at increased salinity and temperature. This has been attributed to the stable repulsive forces of the negatively charged polyelectrolyte of the polymer as salinity increases. From the results obtained in this study, Terminalia mantaly exudate can be a substitute for conventional natural polymers in water-based drilling muds.","PeriodicalId":11250,"journal":{"name":"Day 3 Wed, August 07, 2019","volume":"03 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-08-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86512373","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. Roane, Patrick Patchi Bourgneuf, Kenneth Johnson, M. Williams, V. Chaloupka
A major operator manages multiple, multi-well deep water projects in West Africa. For two such projects in Congo and Nigeria, it was determined that sand control was necessary and a standalone screen (SAS) completion was an efficient and cost-effective means for providing sand control for the majority of wells in both projects. This paper describes a new and unique feature of the SAS completion, called the Dual Isolation Assembly (DIA) that addresses many challenges and its application in Nigeria on the Egina Project. Standard SAS completions incorporate a circulation path down the workstring, through the float shoe, and back to surface through the work string by casing annulus for circulation, pressure maintenance, and removal of the filter cake at the operation's conclusion. The capability to wash down through the toe of the system while running in the well requires washpipe seals inside the float shoe, which incorporates spring-loaded valves that open during pumping but close when pumping stops. In addition to the wash-down capability, the washpipe incorporates a shifter for closing an uphole isolation valve with the ability to reopen the valve, if necessary. For an injector well, the flow path into the formation is through the sand control screens and float shoe from the inside. The path is the opposite for a producer well, which flows from the formation to inside the screen while the float shoe is closed. Because of the different natures of the flow paths, the float shoe is continuously exercised in an injector well as a result of injection fluid starts and stops. During injection, if the opening pressure of the float shoe spring is exceeded, it could stay open over time, causing loss of integrity of the float shoe. When pumping stops, the flow path into the screen through the float shoe could heave formation particles back into the wellbore as a result of the reservoir being energized upon injection shutdown. The DIA provides secondary and permanent isolation of the float shoe, as requested by the operator, and is capable of shifting a barrier isolation valve installed in the lower completion to comply with the operator's barrier policy for deepwater wells. The DIA and lower completion design allows the operator to safely place a filter-cake breaker treatment in the openhole after setting a lower completion packer. In addition to fulfilling the requirements of these SAS completions, the DIA design addresses other potential challenges, such as hydraulic locks and any potential swabbing while manipulating the service tools. This paper describes the evolution of the DIA design and full quality assurance/quality control (QA/QC) and operational procedures, which led to the successful deployment and excellent functionality of the DIA in 12 completions run to date in Nigeria.
{"title":"A Novel Dual Isolation System for Deep Water Injector Standalone Screen Completions","authors":"T. Roane, Patrick Patchi Bourgneuf, Kenneth Johnson, M. Williams, V. Chaloupka","doi":"10.2118/191212-MS","DOIUrl":"https://doi.org/10.2118/191212-MS","url":null,"abstract":"\u0000 A major operator manages multiple, multi-well deep water projects in West Africa. For two such projects in Congo and Nigeria, it was determined that sand control was necessary and a standalone screen (SAS) completion was an efficient and cost-effective means for providing sand control for the majority of wells in both projects. This paper describes a new and unique feature of the SAS completion, called the Dual Isolation Assembly (DIA) that addresses many challenges and its application in Nigeria on the Egina Project.\u0000 Standard SAS completions incorporate a circulation path down the workstring, through the float shoe, and back to surface through the work string by casing annulus for circulation, pressure maintenance, and removal of the filter cake at the operation's conclusion. The capability to wash down through the toe of the system while running in the well requires washpipe seals inside the float shoe, which incorporates spring-loaded valves that open during pumping but close when pumping stops. In addition to the wash-down capability, the washpipe incorporates a shifter for closing an uphole isolation valve with the ability to reopen the valve, if necessary.\u0000 For an injector well, the flow path into the formation is through the sand control screens and float shoe from the inside. The path is the opposite for a producer well, which flows from the formation to inside the screen while the float shoe is closed. Because of the different natures of the flow paths, the float shoe is continuously exercised in an injector well as a result of injection fluid starts and stops. During injection, if the opening pressure of the float shoe spring is exceeded, it could stay open over time, causing loss of integrity of the float shoe. When pumping stops, the flow path into the screen through the float shoe could heave formation particles back into the wellbore as a result of the reservoir being energized upon injection shutdown. The DIA provides secondary and permanent isolation of the float shoe, as requested by the operator, and is capable of shifting a barrier isolation valve installed in the lower completion to comply with the operator's barrier policy for deepwater wells. The DIA and lower completion design allows the operator to safely place a filter-cake breaker treatment in the openhole after setting a lower completion packer.\u0000 In addition to fulfilling the requirements of these SAS completions, the DIA design addresses other potential challenges, such as hydraulic locks and any potential swabbing while manipulating the service tools. This paper describes the evolution of the DIA design and full quality assurance/quality control (QA/QC) and operational procedures, which led to the successful deployment and excellent functionality of the DIA in 12 completions run to date in Nigeria.","PeriodicalId":11250,"journal":{"name":"Day 3 Wed, August 07, 2019","volume":"60 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-06-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84390270","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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