The Experts below are selected from a list of 555 Experts worldwide ranked by ideXlab platform

F Porges - One of the best experts on this subject based on the ideXlab platform.

  • Gas and water coning
    Reservoir Engineering Handbook (Third Edition), 2006
    Co-Authors: F Porges
    Abstract:

    This chapter discusses the Gas and water coning. The objective of this chapter is to provide the theoretical analysis of coning and outline many of the practical solutions for calculating water and Gas coning behavior. Coning is a term used to describe the mechanism underlying the upward movement of water and/or the down movement of Gas into the perforations of a producing well. Coning can seriously impact the well productivity and influence the degree of depletion and the overall recovery efficiency of the oil reservoirs. The specific problems of water and Gas coning are: costly added water and Gas handling, Gas production from the original or Secondary Gas Cap reduces pressure without obtaining the displacement effects associated with Gas drive, reduced efficiency of the depletion mechanism, the water is often corrosive and its disposal costly the afflicted well may be abandoned early, and loss of the total field overall recovery. Finally, coning is primarily the result of movement of reservoir fluids in the direction of least resistance, balanced by a tendency of the fluids to maintain gravity equilibrium.

Tarek Ahmed - One of the best experts on this subject based on the ideXlab platform.

  • Gas and water coning
    Reservoir Engineering Handbook (Fourth Edition), 2010
    Co-Authors: Tarek Ahmed
    Abstract:

    This chapter delves into the theoretical analysis of coning and outlines many of the practical solutions for calculating water and Gas coning behavior, since coning can have an important influence on operations, recovery, and economics. Delaying the encroachment and production of Gas and water are essentially the controlling factors in maximizing the field's ultimate oil recovery. Coning is a term used to describe the mechanism underlying the upward movement of water and the down movement of Gas into the perforations of a producing well. Coning can seriously impact the well productivity and influence the degree of depletion and the overall recovery efficiency of the oil reservoirs. The specific problems of water and Gas coning include various factors. Added water and Gas handling, Gas production from the original or Secondary Gas Cap reduces pressure without obtaining the displacement effects associated with Gas drive and reducing the efficiency of the depletion mechanism are also discussed.

Elias V.l.g. - One of the best experts on this subject based on the ideXlab platform.

  • Gravity Drainage - Lab Tests, Relative Permeability Calculation, And Field Simulation
    2015
    Co-Authors: Bonet E.j., Cunha C., Correa A.c.f., Elias V.l.g.
    Abstract:

    In order to confirm the expected high recoveries obtained in gravity drainage field operations we performed a series of lab tests, developed an oil relative permeability calculation, and used this data to conduct a reservoir simulation for a Brazilian offshore oil field. The lab tests were conducted at ambient temperature and low pressure, and were performed in long cores (90 - 252 cm long) with dead oil and conventional production where the oil was produced at the lower end of the vertically oriented core and air entered the upper end. For one test we performed a counter-current drainage test using live oil where the production was collected at the lower end of the core and the liberated dissolved Gas was removed counter-currently from the upper end. The saturation evolution inside the core was monitored by an X-Ray system. Using the same rock and fluids, centrifuge tests were performed using 3 - 4 cm long plugs to compare to the core displacement test results. When the results did not agree, an explanation for the variance using a model of bundles of Capillary tubes was postulated. Verification using the principle of minimum energy was performed. A computer program was implemented to calculate the oil relative permeability using the lab data, the results of which were compared with the published literature. The calculated relative permeability was used to simulate the behaviour of a Brazilian offshore oil field that was initially exploited with water injection, and then, due to the appearance of a Secondary Gas Cap, subsequently subjected to Gas injection into the crest of the structure.4312227Ayappa, K.G., Davis, H.T., Davis, E.A., Gordon, J., Capillary Pressure: Centrifuge Method Revisited (1989) American Institute of Chemical Engineers Journal, 35 (3), pp. 365-372Blunt, M., Zhou, D., Fenwick, D., Three-Phase Flow and Gravity Drainage in Porous Media (1995) Transport in Porous Media, 20, pp. 77-103Cardwell, W.T., Parsons, R.L., Gravity Drainage Theory (1949) Transcript, American Institute of Mechanical Engineers, 179, pp. 199-215Chatzis, I., Kantzas, A., Dullien, F.L., On the Investigation of Gravity-Assisted Inert Gas Injection Using Micromodels, Long Berea Sandstone Core, and Computer Assisted Tomography (1988) Paper SPE 18284Cunha, M.C., Moretti, A.A., Calculating Capillary Pressure From Single-Speed Centrifuge Experiments (2000) Inverse Problems, Imec Unicamp, p. 1897Dumoré, J.M., Schols, R.S., Drainage Capillary-Pressure Functions and the Influence of Connate Water (1974) Society of Petroleum Engineers Journal, pp. 437-444. , OctoberDykstra, H., The Prediction of Oil Recovery by Gravity Drainage (1978) Journal of Petroleum Technology, pp. 818-829. , MayEdwards, J.T., Honarpour, M.M., Hazlett, R.D., Cohen, M., Membere, A., Pedbani, F., Clayton, C., Al-Hussainy, Validation of Gravity Dominated Relative Permeability and Residual Oil Saturation in a Giant Oil Reservoir (1998) Paper SPE 49316Firoozabadi, A., Aziz, K., Relative Permeability From Centrifuge Data (1986) Paper SPE 15059Foulser, R., Naylor, P., Seale, C., Relative Permeabilities for the Gravity Stable Displacement of Waterflood Residual Oil by Gas (1990) Transcript, Institute of Chemical Engineers, 68 (PART A). , JulyGomes, J.A.T., Tibana, P., Corrêa, A.C.F., Análise Petrográfica e Petrofísica dos Arenitos Berea e Botucatú (1996) Relatório Técnico Unicamp/CepetroHagoort, J., Oil Recovery Drainage (1980) Society of Petroleum Engineers Journal, 20, pp. 139-150. , JuneKalaydjian, F.J.M., Moulu, J.C., Vizika, O., Munkerud, P.K., Three-Phase Flow in Water-Wet Porous Media: Determination of Gas/Oil Relative Permeabilities Under Various Spreading Conditions (1993) Paper SPE 26671Kantzas, A., Chatzis, I., Dullien, F.L., Enhanced Oil Recovery by Inert Gas Injection (1988) Paper SPE 17379Kantzas, A., Chatzis, I., Dullien, F.L., Mechanisms of Capillary Displacement of Oil by Gravity Assisted Inert Gas Injection (1988) Paper SPE 17506Naylor, P., Sargent, N.C., Crosbie, A.J., Tilsed, A.P., Goodyear, S.G., Gravity Drainage During Gas Injection (1995) Proceedings of the 8th European IOR-symposium in Vienna, , Austria, May 15 - 17O'Meara, D.J., Lease, W.O., Multiphase Relative Permeability Measurements Using an Automated Centrifuge (1983) Paper SPE 12128O'Meara, D.J., Crump, J.G., Measuring Capillary Pressure and Relative Permeability in a Single Centrifuge Experiment (1985) Paper SPE 14419Richardson, J.G., Sangree, J.B., Sneider, R.M., Oil Recovery by Gravity Segregation (1989) Journal of Petroleum Technology, pp. 581-582. , JuneSaputelli, L.A., Dawe, R., Grattoni, C., Pore Scale Gravity Drainage Under Different Wettabilities and Multiphase Coexistence (1998) Paper SPE 39621Sahni, A., Burger, J., Blunt, M., Measurement of Three-Phase Relative Permeability During Gravity Drainage Using rCT Scanning (1998) Paper SPE 39655Shook, M., Li, D., Lake, L., Scaling Immiscible Flow Through Permeable Media by Inspectional Analysis (1992) Situ, 16 (4), pp. 311-349Skauge, A., Eleri, O., Graue, A., Monstad, P., Influence of Connate Water on Oil Recovery by Gravity Drainage (1994) Proceedings of the SPE/DOE 9th Symposium on Improved Oil Recovery, , Paper SPE 27817, Tulsa, OK, April 17 - 20Skurdal, H., Hustad, O.St., Holt, T., Oil Recovery by Gravity Drainage During Gas Injection (1995) Proceedings of the 8th IOR-symposium in Vienna, , Austria, MaySkuse, B., Firoozabadi, A., Ramey, H.J., Computation and Interpretation of Capillary Pressure From a Centrifuge (1992) SPE Formation Evaluation, pp. 17-24. , MarchTerwiliger, P.L., Wisley, L.E., Hall, N.H., Bridges, P.M., Morse, R.A., Experimental and Theoretical Investigation of Gravity Drainage Performance (1951) Pet. Transcript, American Institute of Mechanical Engineers, 192, pp. 285-295Vizika, O., Lombard, J.M., Wettability and Spreading: Two Key Parameters in Oil Recovery With Three-Phase Gravity Drainage (1996) SPE Reservoir Engineering, 11, pp. 54-60. , Februar

Rob Kendall - One of the best experts on this subject based on the ideXlab platform.

  • 4d study of Secondary recovery utilizing thai from a saskatchewan heavy oil reservoir
    2014
    Co-Authors: Kurt Wikel, Rob Kendall
    Abstract:

    Heavy oil recoveries in most heavy oil reservoirs in Western Canada are usually less than 10% under primary recovery schemes (native pressure and oil saturation). Thermal methods have been utilized in the Saskatchewan heavy oil region by many operators as a profitable alternative to traditional enhanced oil recovery (EOR) schemes. Petrobank Energy and Resources utilizes Toe to Heel Air Injection (THAI), a patented in-situ combustion technology, to recover large amounts of the remaining resource while upgrading the oil in-situ. Lab results show that THAI can recover up to 65% with an average upgrade of ~8 API, while field results show an average of ~4 API upgrade with recovery amounts still being monitored with time (Kendall and Wikel, 2011). Thermal recovery methods are well suited to monitoring with time lapse seismic. Recent published data shows that heavy oil velocities decrease with added temperature in the lab (Han and Batzle, 2006) and other time lapse case studies show observable and tested time lapse responses when monitoring THAI with seismic (Kendall, 2009; Kendall and Wikel, 2011). In addition, 4D-3C seismic can aid in Caprock integrity monitoring via overburden stress change through time (Wikel et al, 2012). This case study will outline the utilization of a non purpose shot 3D baseline (1995) being interpolated and re-processed to act as a baseline to a recent purpose shot time lapse (2011) near Petrobanks Kerrobert, Saskatchewan THAI facility. Results show an observable compressional wave time lapse response due to the THAI process, which allows us to monitor temperature and Gas migration in active THAI projects. Also, a time lapse response from primary production due to a Secondary Gas Cap in both vertical and horizontal wells is present as well. This Secondary Gas Cap is the result of the reservoir dropping below the bubble point where Gas comes out of solution. The unexpected presence of primary depletion anomalies makes future time lapse shoots over aging heavy oil fields with similar oil properties a possibility for targeted infill drilling.

R Alhussainy - One of the best experts on this subject based on the ideXlab platform.

  • validation of gravity dominated relative permeability and residual oil saturation in a giant oil reservoir
    Software - Practice and Experience, 1998
    Co-Authors: J T Edwards, M M Honarpour, Randy D Hazlett, M F Cohen, A Membere, F Pebdani, C Clayton, R Alhussainy
    Abstract:

    Gravity drainage is normally characterized as a slow but efficient process, leading to a low remaining oil saturation. If the reservoir has a large oil column and a high vertical permeability, then efficient recovery may be achieved through the gravity drainage process that accompanies a stable Gas Cap expansion. An extensive experimental program was conducted to characterize the flow properties of the gravity drainage process where oil is displaced by Gas in the presence of an initial water saturation. The experiments described here were designed to give endpoint saturations, oil relative permeabilities, and Gas relative permeabilities for the Gas-displacing-oil gravity drainage situation. No single test provides all of these parameters required for performance prediction. Long core gravity drainage tests, as well as porous plate and centrifuge tests, were performed at simulated reservoir conditions. The long core drainage tests were conducted in a vertical coreflood apparatus in which in-situ oil and water distributions were monitored regularly using both x-ray and microwave scanning systems. The experimental results support the following conclusions with regard to high permeability, unconsolidated sands: • Residual oil saturation to the gravity drainage process (S org) is low, 3-10% and is somewhat insensitive to rock properties. This level of saturation is achieved through film drainage and may require considerable time and suitable conditions (oil column height and fluid density differences). • Sorg is not sensitive to fluid properties such as viscosity, interfacial tensions, and spreading coefficient for the limited systems studied. • Sorg does not depend on initial water saturation within a reasonable range. • kro and krg depend on rock properties. • Conventional Gas flood tests give higher Sorg (average 30%), even at high volume (1000 PV) and/or low rate Gas injection, and do not represent the gravity drainage process. These laboratory findings were validated by a subsequent coring operation, using a low invasion water-based mud, in the Secondary Gas Cap of the Ubit field, offshore Nigeria, that had been in production for twenty-five years. The residual oil saturations to gravity drainage found in the Secondary Gas Cap agreed well with laboratory results. However, the observed S org was not achieved in the simulation of the field history when detailed geological description and the lab measured k ro was used. Adjustment of kro by an order of magnitude near the Sorg was necessary to match the Sorg distribution observed in the Secondary Gas Cap. It was found that the low kro close to Sorg was an artifact due to Capillary end effects, not fully accounted for in initial modeling. Subsequent lab tests were designed to generate appropriate data for reservoir management. Adjustment of kro was justified when data were reanalyzed, taking P c into consideration, and bringing laboratory measurements, field observations, and reservoir simulation into complete agreement.