The Experts below are selected from a list of 321 Experts worldwide ranked by ideXlab platform
D. T. Perry - One of the best experts on this subject based on the ideXlab platform.
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The Role of Well Testing in Recognizing Deferred Production Revenue
Journal of Energy Resources Technology-transactions of The Asme, 2004Co-Authors: Parviz Mehdizadeh, D. T. PerryAbstract:Well testing is routinely performed to evaluate the performance of a well, which establishes the allocation factor for the lease, which in turn establishes tax and royalty basis. Most well testing is done with conventional gravity separators, which separates the produced stream into oil, water, and gas components and measures these individual components as individual streams. New multiphase measurement technology improves well test results through improved accuracy, consistency, and more frequent well testing. This paper examines the implication of these improved capabilities to recognize well problems and optimize Production. A simple economic model is provided that an operator can use to assess the balance between the cost of performing periodic well tests and the benefits of more quickly discovering well problems that can result in less than expected Production. The model relates the cost of decreased Production, as the result of unforeseen changes in the well, to the frequency and accuracy of the well tests. The model derives an optimum test interval that minimizes the total cost of well testing and Deferred Production on the basis of the probability that a higher than normal decline in Production rate can be detected by well testing. The model is then used in several field examples to assess the optimum period between well tests and how the optimum period can lead to reduced cost of operation and improved Production.
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The Role of Well Testing in Recognizing Deferred Production Revenue
Engineering Technology Conference on Energy Parts A and B, 2002Co-Authors: Parviz Mehdizadeh, D. T. PerryAbstract:Well testing is routinely performed to evaluate the performance of a well, which establishes the allocation factor for the lease, which in turn establishes tax and royalty basis. Most well testing is done with conventional gravity separators, which separates the produced stream into oil, water, and gas components and measures these individual components as individual streams. New multiphase measurement technology improves well test results through improved accuracy, consistency, and more frequent well testing. This paper examines the implication of these improved capabilities to recognize well problems and optimize Production. A simple economic model is provided that an operator can use to assess the balance between the cost of performing periodic well tests and the benefits of more quickly discovering well problems that can result in less than expected Production. The model relates the cost of decreased Production, as the result of unforeseen changes in the well, to the frequency and accuracy of the well tests. The model derives an optimum test interval that minimizes the total cost of well testing and Deferred Production on the basis of the probability that a higher than normal decline in Production rate can be detected by well testing. The model is then used in several field examples to assess the optimum period between well tests and how the optimum period can lead to reduced cost of operation and improved Production.Copyright © 2002 by ASME
A.l. Franzen - One of the best experts on this subject based on the ideXlab platform.
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Acid-Sludge Characterization and Remediation Improve Well Productivity and Save Costs in the Permian Basin
Spe Production & Facilities, 1997Co-Authors: T.c. Wong, R.j. Hwang, D.w. Beaty, J.d. Dolan, R.a. Mccarty, A.l. FranzenAbstract:Many oil wells in the Permian Basin have reported sludging problems associated with acid stimulations. The acid sludge is similar among wells and was identified as a viscous emulsion stabilized by asphaltene-rich organic solids. The sludging tendency of the oil increased with the concentrations of asphaltenes and resins, base number of the oil, and ferric ion content in the acid. Only three out of nine commercial acid systems tested were effective in preventing acid-sludge formation; they all use the same novel iron control technology, i.e., catalytic reduction of ferric ions. Several commercial and generic solvent systems were effective in dissolving acid sludge, including mixtures of an aromatic solvent (e.g., xylene) with either isopropyl alcohol (2:1 volume ratio), or ethylene glycol-monobutylether (EGMBE) (2:1 to 3:1 volume ratios). Selection of acid formulations and solvent systems was based on cost effectiveness and operation safety. Field implementation proved successful. If the results of this study had been implemented earlier in the lives of some of the Permian Basin properties, the recovery of 574 BOPD of lost or Deferred Production from 99 wells could have been realized. This would have resulted in an estimated increased revenue of over US $3 million in 1 year.
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Acid Sludge Characterization and Remediation Improve Well Productivity
All Days, 1996Co-Authors: T.c. Wong, R.j. Hwang, D.w. Beaty, J.d. Dolan, R.a. Mccarty, A.l. FranzenAbstract:Abstract Many oil wells in the Permian Basin have reported sludging problems associated with acid stimulations. The acid sludge is similar among wells and was identified as a viscous emulsion stabilized by asphaltene-rich organic solids. The sludging tendency of the oil increased with the concentrations of asphaltenes and resins, base number of the oil, and ferric ion content in the acid. Only three out of nine commercial acid systems tested were effective in preventing acid sludge formation; they all utilize the same novel iron control technology, i.e., catalytic reduction of ferric ions. Several commercial and generic solvent systems were effective in dissolving acid sludge, including mixtures of an aromatic solvent (e.g. xylene) with either isopropyl alcohol (2:1 volume ratio) or EGMBE (2:1 to 3:1 volume ratios). Selection of acid formulations and solvent systems was based on cost effectiveness and operation safety. Field implementation proved successful. If the results of this study had been implemented earlier in the lives of some of the Permian Basin properties, the recovery of 574 BOPD of lost or Deferred Production from 99 wells could have been realized. This would have resulted in an estimated increased revenue of over $3 million in one year. Introduction Various fields in the Permian Basin in West Texas have reported a "sludging" problem associated with acid stimulation. This sludge, more commonly known as "acid sludge," was found to occur in both producer and injector wells in the Permian Basin. In some cases, acid sludge was related to CO2 breakthrough. Samples recovered from all of the above situations appeared to be quite voluminous, viscous, and stable indefinitely. This resulted in a dramatic reduction of oil Production or water injection rate in some of the wells. Early studies have revealed that crude oils in many producing areas of the United States and Canada form acid sludge upon contact with acid. The acid sludge potentially plugs pore throats, pores, vugs, wormholes, and natural fractures and produces skin damage which significantly reduces permeability in the near-wellbore region. Acid sludge can cause damage that partially, if not totally, offsets the stimulating benefit of the acid. However, the composition and chemical structure of acid sludge have not been well understood. It has been reported that acid sludge is asphaltenic in nature; can exist in some form of an emulsion, solids, or a mixture of both; and may not dissolve in solvents. Asphaltic components of crude oils, which are generally present in colloidal state, are apparently destabilized by low pH as a result of acid contact.
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Acid-Sludge Characterization and Remediation Improve Well Productivity and Save Costs in the Permian Basin
Proceedings of Permian Basin Oil and Gas Recovery Conference, 1996Co-Authors: T.c. Wong, R.j. Hwang, D.w. Beaty, J.d. Dolan, R.a. Mccarty, A.l. FranzenAbstract:Many oil wells in the Permian Basin have reported sludging problems associated with acid stimulations. The acid sludge is similar among wells and was identified as a viscous emulsion stabilized by asphaltene-rich organic solids. The sludging tendency of the oil increased with the concentrations of asphaltenes and resins, base number of the oil, and ferric ion content in the acid. Only three out of nine commercial acid systems tested were effective in preventing acid sludge formation ; they all utilize the same novel iron control technology, i.e., catalytic reduction of ferric ions. Several commercial and - generic solvent systems were effective in dissolving acid sludge, including mixtures of an aromatic solvent (e.g. xylene) with either isopropyl alcohol (2 :1 volume ratio) or EGMBE (2 :1 to 3 :1 volume ratios). Selection of acid formulations and solvent systems was based on cost effectiveness and operation safety. Field implementation proved successful. If the results of this study had been implemented earlier in the lives of some of the Permian Basin properties, the recovery of 574 BOPD of lost or Deferred Production from 99 wells could have been realized. This would have resulted in an estimated increased revenue of over $3 million in one year.
Parviz Mehdizadeh - One of the best experts on this subject based on the ideXlab platform.
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The Role of Well Testing in Recognizing Deferred Production Revenue
Journal of Energy Resources Technology-transactions of The Asme, 2004Co-Authors: Parviz Mehdizadeh, D. T. PerryAbstract:Well testing is routinely performed to evaluate the performance of a well, which establishes the allocation factor for the lease, which in turn establishes tax and royalty basis. Most well testing is done with conventional gravity separators, which separates the produced stream into oil, water, and gas components and measures these individual components as individual streams. New multiphase measurement technology improves well test results through improved accuracy, consistency, and more frequent well testing. This paper examines the implication of these improved capabilities to recognize well problems and optimize Production. A simple economic model is provided that an operator can use to assess the balance between the cost of performing periodic well tests and the benefits of more quickly discovering well problems that can result in less than expected Production. The model relates the cost of decreased Production, as the result of unforeseen changes in the well, to the frequency and accuracy of the well tests. The model derives an optimum test interval that minimizes the total cost of well testing and Deferred Production on the basis of the probability that a higher than normal decline in Production rate can be detected by well testing. The model is then used in several field examples to assess the optimum period between well tests and how the optimum period can lead to reduced cost of operation and improved Production.
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The Role of Well Testing in Recognizing Deferred Production Revenue
Engineering Technology Conference on Energy Parts A and B, 2002Co-Authors: Parviz Mehdizadeh, D. T. PerryAbstract:Well testing is routinely performed to evaluate the performance of a well, which establishes the allocation factor for the lease, which in turn establishes tax and royalty basis. Most well testing is done with conventional gravity separators, which separates the produced stream into oil, water, and gas components and measures these individual components as individual streams. New multiphase measurement technology improves well test results through improved accuracy, consistency, and more frequent well testing. This paper examines the implication of these improved capabilities to recognize well problems and optimize Production. A simple economic model is provided that an operator can use to assess the balance between the cost of performing periodic well tests and the benefits of more quickly discovering well problems that can result in less than expected Production. The model relates the cost of decreased Production, as the result of unforeseen changes in the well, to the frequency and accuracy of the well tests. The model derives an optimum test interval that minimizes the total cost of well testing and Deferred Production on the basis of the probability that a higher than normal decline in Production rate can be detected by well testing. The model is then used in several field examples to assess the optimum period between well tests and how the optimum period can lead to reduced cost of operation and improved Production.Copyright © 2002 by ASME
T.c. Wong - One of the best experts on this subject based on the ideXlab platform.
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Acid-Sludge Characterization and Remediation Improve Well Productivity and Save Costs in the Permian Basin
Spe Production & Facilities, 1997Co-Authors: T.c. Wong, R.j. Hwang, D.w. Beaty, J.d. Dolan, R.a. Mccarty, A.l. FranzenAbstract:Many oil wells in the Permian Basin have reported sludging problems associated with acid stimulations. The acid sludge is similar among wells and was identified as a viscous emulsion stabilized by asphaltene-rich organic solids. The sludging tendency of the oil increased with the concentrations of asphaltenes and resins, base number of the oil, and ferric ion content in the acid. Only three out of nine commercial acid systems tested were effective in preventing acid-sludge formation; they all use the same novel iron control technology, i.e., catalytic reduction of ferric ions. Several commercial and generic solvent systems were effective in dissolving acid sludge, including mixtures of an aromatic solvent (e.g., xylene) with either isopropyl alcohol (2:1 volume ratio), or ethylene glycol-monobutylether (EGMBE) (2:1 to 3:1 volume ratios). Selection of acid formulations and solvent systems was based on cost effectiveness and operation safety. Field implementation proved successful. If the results of this study had been implemented earlier in the lives of some of the Permian Basin properties, the recovery of 574 BOPD of lost or Deferred Production from 99 wells could have been realized. This would have resulted in an estimated increased revenue of over US $3 million in 1 year.
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Acid Sludge Characterization and Remediation Improve Well Productivity
All Days, 1996Co-Authors: T.c. Wong, R.j. Hwang, D.w. Beaty, J.d. Dolan, R.a. Mccarty, A.l. FranzenAbstract:Abstract Many oil wells in the Permian Basin have reported sludging problems associated with acid stimulations. The acid sludge is similar among wells and was identified as a viscous emulsion stabilized by asphaltene-rich organic solids. The sludging tendency of the oil increased with the concentrations of asphaltenes and resins, base number of the oil, and ferric ion content in the acid. Only three out of nine commercial acid systems tested were effective in preventing acid sludge formation; they all utilize the same novel iron control technology, i.e., catalytic reduction of ferric ions. Several commercial and generic solvent systems were effective in dissolving acid sludge, including mixtures of an aromatic solvent (e.g. xylene) with either isopropyl alcohol (2:1 volume ratio) or EGMBE (2:1 to 3:1 volume ratios). Selection of acid formulations and solvent systems was based on cost effectiveness and operation safety. Field implementation proved successful. If the results of this study had been implemented earlier in the lives of some of the Permian Basin properties, the recovery of 574 BOPD of lost or Deferred Production from 99 wells could have been realized. This would have resulted in an estimated increased revenue of over $3 million in one year. Introduction Various fields in the Permian Basin in West Texas have reported a "sludging" problem associated with acid stimulation. This sludge, more commonly known as "acid sludge," was found to occur in both producer and injector wells in the Permian Basin. In some cases, acid sludge was related to CO2 breakthrough. Samples recovered from all of the above situations appeared to be quite voluminous, viscous, and stable indefinitely. This resulted in a dramatic reduction of oil Production or water injection rate in some of the wells. Early studies have revealed that crude oils in many producing areas of the United States and Canada form acid sludge upon contact with acid. The acid sludge potentially plugs pore throats, pores, vugs, wormholes, and natural fractures and produces skin damage which significantly reduces permeability in the near-wellbore region. Acid sludge can cause damage that partially, if not totally, offsets the stimulating benefit of the acid. However, the composition and chemical structure of acid sludge have not been well understood. It has been reported that acid sludge is asphaltenic in nature; can exist in some form of an emulsion, solids, or a mixture of both; and may not dissolve in solvents. Asphaltic components of crude oils, which are generally present in colloidal state, are apparently destabilized by low pH as a result of acid contact.
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Acid-Sludge Characterization and Remediation Improve Well Productivity and Save Costs in the Permian Basin
Proceedings of Permian Basin Oil and Gas Recovery Conference, 1996Co-Authors: T.c. Wong, R.j. Hwang, D.w. Beaty, J.d. Dolan, R.a. Mccarty, A.l. FranzenAbstract:Many oil wells in the Permian Basin have reported sludging problems associated with acid stimulations. The acid sludge is similar among wells and was identified as a viscous emulsion stabilized by asphaltene-rich organic solids. The sludging tendency of the oil increased with the concentrations of asphaltenes and resins, base number of the oil, and ferric ion content in the acid. Only three out of nine commercial acid systems tested were effective in preventing acid sludge formation ; they all utilize the same novel iron control technology, i.e., catalytic reduction of ferric ions. Several commercial and - generic solvent systems were effective in dissolving acid sludge, including mixtures of an aromatic solvent (e.g. xylene) with either isopropyl alcohol (2 :1 volume ratio) or EGMBE (2 :1 to 3 :1 volume ratios). Selection of acid formulations and solvent systems was based on cost effectiveness and operation safety. Field implementation proved successful. If the results of this study had been implemented earlier in the lives of some of the Permian Basin properties, the recovery of 574 BOPD of lost or Deferred Production from 99 wells could have been realized. This would have resulted in an estimated increased revenue of over $3 million in one year.
Jocabeth Ramos - One of the best experts on this subject based on the ideXlab platform.
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Using Coiled Tubing as Sucker Rods for SRP
All Days, 2012Co-Authors: Fernando Sebastian Flores-avila, Juan Manuel Riano, Marcos Javier-martinez, Tony Hammond, Joel Cantu, Jocabeth RamosAbstract:Abstract Sucker rod Pumping (SRP) has been among the most efficient artificial lift systems. This method has proven to be one of the most popular ones while having some modifications in the prime mover systems, using hydraulic, pneumatic or mechanical devices. However, one of the most frequently encountered problems with this system is that while the well is being produced, sand is dragged from the formation to the well. Whether it comes from the fracture (propant) or the formation itself, this interferes with the pumping system and the fluid flow to the surface. In SRP, fluid flow velocity is not enough to maintain sand suspended so that it could be brought up to the surface, ending up precipitated and being deposited on top of the pump causing a reduction in efficiency and premature wear of the pump components, if not stocking the pump at all. Due to this effect, the well must be scheduled for work over in order to remove the sand. This implies to move and de-move a work over rig which can take several days with the associated cost and Deferred Production. Using Coiled Tubing instead of a sucker rod string, maintenance can be achieved to the well through pumping and circulating fluids without having to remove the string and bottom hole pump, taking just about a couple of hours to perform the job. Production can be restored in few hours, reducing down time, maximizing well Production. It also can be used in a preventive mode by pumping chemicals that will help fluid flow by preventing scale build up and viscosity reduction in the case of heavy and viscous crude oils. Coiled tubing string is designed to fit specific needs such as depth, pressure, and loads expected during the operation. It may vary in diameter, wall thickness, and stiffness. This paper describes the first time application in México for this technology which offers a great potential in mature fields. It also describes coiled tubing design criteria as well as string evaluation after the trial test performed.
