Real-Time Fluid Distribution Determination in Matrix Treatments Using DTS
- Gerard Glasbergen (Halliburton Energy Services Group) | Dan Gualtieri (Halliburton Energy Services) | Mary S. Van Domelen (Maersk Oil) | José Sierra (WellDynamics)
- Document ID
- Society of Petroleum Engineers
- SPE Production & Operations
- Publication Date
- February 2009
- Document Type
- Journal Paper
- 135 - 146
- 2009. Society of Petroleum Engineers
- 5.3.2 Multiphase Flow, 5.1.5 Geologic Modeling, 2.2.2 Perforating, 5.6.4 Drillstem/Well Testing, 5.9.2 Geothermal Resources, 5.6.5 Tracers, 4.5.3 Floating Production Systems, 3.2.3 Hydraulic Fracturing Design, Implementation and Optimisation, 1.10 Drilling Equipment, 4.2.3 Materials and Corrosion, 4.3.4 Scale, 5.8.7 Carbonate Reservoir, 5.6.11 Reservoir monitoring with permanent sensors, 4.1.2 Separation and Treating, 3.2.4 Acidising, 5.6.1 Open hole/cased hole log analysis, 1.8 Formation Damage
- 11 in the last 30 days
- 1,171 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 5.00|
|SPE Non-Member Price:||USD 35.00|
In matrix treatments, placement of the injected fluids is essential for success. Over the years, several diversion and placement techniques have been applied to obtain a desired fluid distribution. Real-time evaluation of a treatment was limited to observing injection pressures or bottomhole pressures. These measured pressures provided information on the diversion process. The application of distributed-temperature sensing (DTS) during matrix treatments to monitor the temperature profiles along the wellbore in real time is a recent method to obtain a qualitative indication of the fluid distribution. In this paper, we discuss if DTS can also be used to quantify the fluid distribution during a matrix treatment.
For the real-time quantification of the fluid distribution during a matrix treatment from temperature surveys, both real-time readouts of the temperature surveys and an accurate real-time model are needed. With DTS, the real-time readout is a feasible technique developed to present and evaluate the temperature surveys in real time. Further, a coupled wellbore and near-wellbore thermal model is available that runs in real time. This paper describes these techniques, models, and validations using several case histories.
In addition, an analysis of matrix treatments using DTS temperature surveys, where available, are presented. The models are used in the analysis to obtain calculated fluid flow distribution. We discuss how this methodology can be applied in real time and what benefits quantification of fluid flow distribution offers. Further, we describe what other benefits can be obtained from real-time temperature profiles during stimulation treatments.
|File Size||3 MB||Number of Pages||12|
Behenna, F.R. 1994. Interpretation of Matrix AcidizingTreatments Using a Continuously Monitored Skin Factor. Paper SPE 27401presented at the SPE International Symposium on Formation Damage Control,Lafayette, Louisiana, USA, 7-10 February. DOI: 10.2118/27401-MS.
Brown, G., Storer, D., McAllister, S., Al-Asimi, M., and Raghavan, K. 2003.Monitoring Horizontal Producersand Injectors During Cleanup and Production Using Fiber-Optic-DistributedTemperature Measurements. Paper SPE 84379 presented at the SPE AnnualTechnical Conference and Exhibition, Denver, 5-8 October. DOI:10.2118/84379-MS.
Buijse, M.A. and Glasbergen, G. 2005. A Semiempirical Model to CalculateWormhole Growth in Carbonate Acidizing. Paper SPE 96892 presented at theSPE Annual Technical Conference and Exhibition, Dallas, 9-12 October. DOI:10.2118/96892-MS.
Carnahan, B.D., Clanton, R.W., Koehler, K.d., Harkins, G.O., and Williams,G.R. 1999. Fiber Optic TemperatureMonitoring Technology. Paper SPE 54599 presented at the SPE WesternRegional Meeting, Anchorage, 26-27 May. DOI: 10.2118/54599-MS.
Chiu, K. and Thakur, S.C. 1991. Modeling of Wellbore Heat Losses inDirectional Wells Under Changing Injection Conditions. Paper SPE 22870presented at the SPE Annual Technical Conference and Exhibition, Dallas, 6-9October. DOI: 10.2118/22870-MS.
Clanton, R., Haney, J.A., Pruett, R., Wahl, C.L., Goiffon, J.J., andGualtieri, D. 2006. Real-TimeMonitoring of Acid Stimulation Using a Fiber-Optic DTS System. Paper SPE100617 presented at the SPE Western Regional/AAPG Pacific Section/GSACordilleran Section Joint Meeting, Anchorage, 8-10 May. DOI:10.2118/100617-MS.
Glasbergen, G. and Buijse, M. 2006. Improved Acid Diversion Design Usinga Placement Simulator. Paper SPE 102412 presented at the SPE Russian Oiland Gas Technical Conference and Exhibition, Moscow, 3-6 October. DOI:10.2118/102412-MS.
Goiffon J., and Gualtieri, D. 2006. Fiber-Optic Real-Time DistributedTemperature Sensing Provides Improved Management for Heavy-Oil ProductionEnvironments. Paper OTC 18140 presented at the Offshore Technology Conference,Houston, 1-4 May.
Johnson, D., Sierra, J., Gualtieri, D., and Kaura, J. 2006. DTS Transient Analysis: A New ToolTo Assess Well-Flow Dynamics. Paper SPE 103093 presented at the SPE AnnualTechnical Conference and Exhibition, San Antonio, Texas, USA, 24-27 September.DOI: 10.2118/103093-MS.
Jones, A.T. and Davies, D.R. 1998. Quantifying Acid Placement: The Keyto Understanding Damage Removal in Horizontal Wells. SPE Prod &Fac 13 (3): 163-169. SPE-50975-PA. DOI: 10.2118/50975-PA.
Kabir, C.S., Hasan, A.R., Kouba, G.E., and Ameen, M. 1996. Determining Circulating FluidTemperature in Drilling, Workover, and Well-Control Operations. SPEDrill & Compl 11 (2): 74-79. SPE-24581-PA. DOI:10.2118/24581-PA.
Liang-Biao, O. and Belanger, D. 2006. Flow Profiling via DistributedTemperature Sensor (DTS) System--Expectation and Reality. SPE Prod &Oper 21 (2): 269-281. SPE-90541-PA. DOI: 10.2118/90541-PA.
Lynn, J.D. and Nasr-El-Din, H.A. 2001. A Core Based Comparison of theReaction Characteristics of Emulsified and In-Situ Gelled Acids in LowPermeability, High Temperature, Gas Bearing Carbonates. Paper SPE 65386presented at the SPE International Symposium on Oilfield Chemistry, Houston,13-16 February. DOI: 10.2118/65386-MS.
McLeod, H.P. and Coulter, A.W. 1969. The Stimulation Treatment PressureRecord: An Overlooked Formation Evaluation Tool. J. Pet Tech21 (8): 951-960. SPE-2287-PA. DOI: 10.2118/2287-PA.
Medeiros, F. Jr. and Trevisan, O.V. 2006. Thermal analysis inmatrix acidization. Journal of Petroleum Science and Engineering51 (1-2): 85-96. DOI:10.1016/j.petrol.2005.11.011.
Nasr-El-Din, H.A., Driweesh, S.M., and Muntasheri, G.A. 2003. Field Application of HCl-Formic AcidSystem to Acid Fracture Deep Gas Wells Completed with Super Cr-13 Tubing inSaudi Arabia. Paper SPE 84925 presented at the SPE International ImprovedOil Recovery Conference in Asia Pacific, Kuala Lumpur, 20-21 October. DOI:10.2118/84925-MS.
Nasr-El-Din, H.A., Kritzler, T., and Cassidy, J. 2002. Recent Developments inHigh-Temperature Acidizing with Super 13Cr Completions: Laboratory Testing.Paper SPE 78557 presented at the Abu Dhabi International Petroleum Exhibitionand Conference, Abu Dhabi, United Arab Emirates, 13-16 October. DOI:10.2118/78557-MS.
Paccaloni, G. 1979. Field History Verifies Control, Evaluation. Oil andGas Journal 77 (26 November 1979): 61-65.
Paccaloni, G. 1995. A New,Effective Matrix Stimulation Diversion Technique. SPE Prod & Fac10 (3): 151-156. SPE-24781-PA. DOI: 10.2118/24781-PA.
Paccaloni, G. and Tambini, M. 1993. Advances in Matrix StimulationTechnology. J. Pet Tech 45 (3): 256-263. SPE-20623-PA.DOI: 10.2118/20623-PA.
Prensky, S. 1992. Temperature Measurements in Boreholes: An Overview ofEngineering and Scientific Applications. The Log Analyst 33(3): 313-333.
Prouvost, L.P. and Economides, M.J. 1989. Applications of Real-TimeMatrix-Acidizing Evaluation Method. SPE Prod Eng 4 (4):401-407. SPE-17156-PA. DOI: 10.2118/17156-PA.
Ramey, H.J. Jr. 1962. WellboreHeat Transmission. J. Pet Tech 14 (4): 427-435;Trans., AIME, 225. SPE-96-PA. DOI: 10.2118/96-PA.
Selle, O.M., Springer, M., Auflem, I.H., Chen, P., Matheson, J.R., Mebratu,A., and Glasbergen, G. 2008. Gelled Scale Inhibitor Treatment forImproved Placement in Long Horizontal Wells at Norne and Heidrun Fields.Paper SPE 112464 presented at the SPE Symposium and Exhibition on FormationDamage Control, Lafayette, Louisiana, USA, 13-15 February. DOI:10.2118/112464-MS.
Skinner, N.G. and Maida, J.L. Jr. 2004. Downhole fiber optic sensing: Theoilfield service provider's perspective. In Fiber Optic Sensor Technologyand Applications III: Proceedings of SPIE Volume 5589, ed. M.A. Marcus, B.Culshaw, and J.P. Dakin, 206-220.
Witterholt, E.J. and Tixier, M.P. 1972. Temperature Logging in InjectionWells. Paper SPE 4022 presented at the Fall Meeting of the Society ofPetroleum Engineers of AIME, San Antonio, Texas, USA, 8-11 October. DOI:10.2118/4022-MS.
Wooley, G.R. 1980. ComputingDownhole Temperatures in Circulation, Injection, and Production Wells.J. Pet Tech 32 (9): 1509-1522. SPE-8441-PA. DOI:10.2118/8441-PA.