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Construction and calibration of a fractured tight reservoir model
- 1. CONSTRUCTION AND CALIBRATION OF A FRACTURED TIGHT RESERVOIR MODEL Speaker: J. Marin AAPG YP - 2016
- 2. Introduction Objectives Available data Identifying fractures Geomechanical model Modeling natural fracture networks Validation of the reservoir model Optimal well orientation Conclusions
- 3. Introduction Cuenca Tumbes-Progreso Cuenca Talara Cuenca Lancones Cuenca Sechura Located in the Talara Basin on Peru’s northern coast, with a total extension of 470 km2 and 3,226 active wells out of over 5,000 total drilled to date. Sedimentary fill of Talara Basin is roughly 9,000 meters thick with main productive intervals of the Eocene period. Structural and Stratigraphic Complexity Low porosity and low permeability Deep reservoirs with natural fracturing Hidraulic Fracturing needed Commingled production Solution gas Mechanism Limited información of electric logs, PVT y pressure CRONOESTRATIGRAFIA LITOESTRATIGRAFIA PLEISTOCENO Disc Disc SUPERIOR PRIABONIANO Disc Disc HELICO LOBITOS TEREBRATULA Disc BALLENA CONSTANCIA SOMATITO VERDE CABO BLANCO CLAVEL Disc LAGOON PEÑA NEGRA OSTREA "C" OSTREA "D" OSTREA "E" Disc MOGOLLON MED MOGOLLON INF ZAMBO TUNEL NEGRITOS PTA. ARENAS Disc Disc Disc Disc Disc BASAL SALINA LA DRAGA LUTITAS TALARA MONTE INFERIOR YPRESIANO SALINAS ECHINO SENONIANOGALICO THANETIANO LUTETIANO CAMPANIANO PETACAS MALPASO MAESTRICHTIANO PENSILVANIANO INF. MUERTO PANANGA ALBIANO APTIANO CARBONIFERO PALEOZOICO PERMICO AMOTAPE PALAUS CERRO PRIETO MESOZOICO CRETACEO SUPERIOR ANCHA REDONDO TABLONES COPA SOMBREROSANTONIANO PALEOCENO SUP. BALCONES INF. MESA OSTREA MOGOLLON MOGOLLON SUP SAN CRISTOBAL ARENISCAS TALARA CARPITAS MIRADOR CHIRA VERDUN LAGUNITOS BARTONIANO OLIGOCENO RUPELIANO INFERIORMEDIO EOCENO TALARA POZO UNIDAD PRODUCTIVA CENOZOICO CUATERNARIO TABLAZO PALEOGENO MANCORA GRUPO FORMACION MIEMBRO LITOLOGIA ERA SISTEMA SERIE PISO Calizasmicrít Conglomerad Areniscasgri Lutitasgrisos Disc CERRO NEGRO PENSILVANIANO MISSISSIPIANO CARBONIFERO PALEOZOICO PERMICO AMOTAPE PALAUS CERRO PRIETO CHALECO DE PAÑO DEVONICO Stratigrraphic column – Talara Basin (Modified by G. Pozo, 2008) Talara basin location, tectonic elements and block X (Daudt, 2009)
- 4. ECHINO MOGOLLON AMOTAPE BASAL SALINA ECHINOCYAMUS MOGOLLON BASAL SALINA AMOPATE • High structural complexity (faults and fractures) • Normal faulting in a mainly extensional regime • Compartmentalized reservoirs • Horst and graben configuration Introduction
- 5. Identify the natural fractures that contributes to the flow and their distribution in Mogollon formation Construction of a fractured tight reservoir model Calibration of the 3D fracture network model with historical production Objectives
- 6. Field observations (25 km to the southeast) Stratigraphic model Structural features: Interpreted cross sections based on well logs Cores analysis (stratigraphic and petrophysical studies) Geomechanical data Well logs (borehole images) Dynamic data (well testing, production, mud losses) Available data – Mogollon Fm Well testing data Production data Outcrops of Mogollon Fm. Cross section based on well logs Core and borehole imaga information
- 7. Paleocurrents direction (from Carozzi & Palomino, 1993) Secondary paleocurrent direction (from Daudt et al (2003)) 1. Fluvial Domain 2. Upper Fan (fluvial/delta plain transition?) 3. Middle Fan (delta plain) 4. Lower Fan (delta front) 5. Delta front/Prodelta transition 6. Prodelta 7. Proximal Alluvial Fans Mogollon Fm: Depositional model
- 8. Chorro Superior Fm. San Cristobal Fuente Chorro Inferior FormaciónMogollón Litoestratigrafía Perfil de pozo Ciclos T/R Contexto depositacional Superior FSST/LST Continental Transicional Secuencias Supercicies Medio Inferior Fm. Ostrea SECCION ESTRUCTURAL EA7944 7944 TD=6030 Correlation Depth Oil Resistivity Lt.Gray Oil -3500 -3500 -4000 -4000 -4500 -4500 -5000 -5000 MO_mrs SC_MO_unc MO_IM_mfs MO_MS_unc CHORRO SUP. CHORRO INF. FUENTE MOGOLLON MEDIO MOGOLLON INF. MOGOLLON 5665 1762 7913 7944 1340 2394 1132 5898 6583 1590 1886 1857 1892 MOGOLLON Fm. : STRATIGRAPHIC SECTION NESW Thickness map of reservoir facies – Mogollon formation – Alluvial fan deposits – Coast Area Mogollon Fm: Stratigraphic model
- 9. Interpreted structural section based on well logs EC1825EC1822 EC1114 EC1820 EC1388EC2201 EC1954EC1096 -500 -1000 -1500 -2000 -2500 -3000 -3500 -4000 -4500 -5000 -5500 -6000 -6500 -7000 -7500 -8000 -8500 -9000 -9500 1000 500 0 -500 -1000 -1500 -2000 -2500 -3000 -3500 -4000 -4500 -5000 -5500 -6000 -6500 -7000 -7500 -8000 -8500 -9000 -9500 1000 500 0 EC2203 V E R D U N C H I R A A M O T A P E M O G O L L O N S U P. T A B L A Z O P E N A N E G R A E C H I N O R E P . II H E L I C O R E P. O S T R E A R E P. M O G O L L O N M E D I O NW SE Mogollon Fm: Structural features
- 10. • Medium to coarse grained sandstones and conglomerates • Thickness of fm of 1800 to 2000 ft • Low matrix porosities (4-6%) • Low matrix permeabilities (0.01 – 0.1md) • Production comes from fractured Low-permeabilitiy sandstones Mogollon Fm: Reservoir features Conglomerate
- 11. Identifying fractures – Field observations Fractures (dashed black lines) related to normal fault (red line) with azimuth/dip: N340°/50° in Qda. Salado (25 km to the southeast of Block X), Mogollon Formation.
- 12. Identifying fractures – Core analysis Matrix properties
- 13. Identifying fractures – Core analysis
- 14. Identifying fractures – Core analysis
- 15. Identifying fractures – Borehole image log
- 16. Identifying fractures – Dynamic data Data for tested interval Hn = 60 Phi = 0.063 Sw = 0.581 K = 0.051 KH from well test interpretations (md.ft) 114 KH from logs (md.ft) 3.1 FCI: Fracture capacity index (Narr et al., 2006) 37.3 Escobedo, 2012
- 17. Identifying fractures – Dynamic data Data for tested interval Hn = 20 Phi = 0.051 Sw = 0.593 K = 0.035 KH from well test interpretations (md.ft) 15 KH from logs (md.ft) 0.70 FCI: Fracture capacity index (Narr et al., 2006) 21.4 Escobedo, 2012
- 18. Identifying fractures – Dynamic data Oil, bbl/d Total fluid, bbl/d Water cut, % Figure from Jolley et al, 2008 Type II (Pozo, 2008)
- 19. 0 200 400 600 800 1000 1200 0 100 200 300 400 500 CaudalbrutO(bbls/d) # de fracturas abiertas Relación Fracturas abiertas y Caudal Inicial Bruto 8063D 8031 8052 8062D 8067D Benito & Pozo, 2008 Identifying fractures – Fractures and production B A C D E
- 20. Geomechanical model– source of information Sv Shmax ShminPp, E,v,UCS Sv: Vertical stress (Overburden) – Density logs / cuttings Shmin: least principal stress – Minifrac tests / leak-off tests / Vp-Vs / drilling data Shmax: Maximum horizontal stress – borehole image logs (stress polygon) / correlations (Pp-Shmin-UCS) Pp: Pore pressure – DST / MDT / Seismic data Stress orientation: Caliper logs (multiple arms), Borehole image logs, velocity anisotropy, structural maps, 3D seismica data, focal plane mechanism Young (E) modulus, poisson’s ratio (v): Vp-Vs-Density / laboratory test on cores Unconfined compressive strength (UCS), friction angle (Ф): Vp-Vs-Density / laboratory test on cores
- 21. Source: Pozo, 2008 Geomechanical model: Elastic modulus Source: Petrobras, 2009 G: Shear modulus E: Young’s modulus K: Bulk modulus Vp: Compressional waveus Vs: Shear waves
- 22. A partir del Perfil Sónico de Onda Completa se obtienen los módulos dinámicos, los cuales deben ser ajustados con los datos de laboratorio para obtener los estáticos para diseñar. Es necesario disponer de las curvas de tiempo de tránsito compresional y de cizalla obtenidas del tren de ondas completo registrado por la Herramienta Sónica, )/1(* )/34(* 10*34,1 222 22 10 tctsts tctsRhob Ed )/1(*2 /2 22 22 tcts tcts d Rhob: Curva Perfil Densidad [gr/cc] tcTiempo de tránsito compresional [ s/ft] tsTiempo de tránsito de cizalla [ s/ft] Geomechanical model: Elastic modulus
- 23. Geomechanical model: Cohesion-UCS Zoback, 2007 Source: Petrobras, 2009
- 24. Geomechanical model: Pore pressure 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 0 500 1000 1500 2000 2500 3000 3500 Pressure (psi) Depth(ss-ft) DEPLETION Gi= 0.58 psi/ft Pore pressure gradient – Mogollon fm. Zoback, 2007 Pressure History 0 500 1000 1500 2000 2500 3000 3500 Oct-54 Mar-60 Sep-65 Mar-71 Ago-76 Feb-82 Ago-87 Ene-93 Jul-98 Ene-04 Jul-09 Date Pressure(psi)
- 25. Geomechanical model – Stress Orientation Breakout analisys Fracture system – Upper Mogollon Source: E. Bustamante, 2013 Azimuth of Shmax: 56°
- 26. Geomechanical model – Sv ; Jaeger and cook, 1971 Average density in sedimantary rocks: 23 Mpa /Km (aprox 1 psi/ft) Pp (psi/ft): 0.38 Sv(psi/ft): 1.089 Overburden gradient for the area:
- 27. Geomechanical model – Shmin Minifrac test Well – Mogollon Fm. Depth (ft): 6501 ISIP (psi): 3860.9 Smin (psi/ft):0.594 K (md):0.69 Depth (ft): 6212 ISIP (psi): 3670 Smin (psi/ft): 0.591 K (md): 1.27 Source: Guisado, L.
- 28. 0.50 1.00 1.50 2.00 2.50 3.00 0.50 1.00 1.50 2.00 2.50 3.00 Shmax(PSI/Foot Sh min (PSI/Foot) RF SS NF Geomechanical model: Constraining Shmax from Wellbore Failure Tensile fractures Breakouts for given UCS Shmin from minifrac Pp : 0.380 psi/ft Azimuth of Shmax: 56° Shmin: 0.591 psi/ft Sv: 1.089 psi/ft Biot coefficient=1 Posson’s ratio=0.23 Breakout width = 0° Diff. Mud pressure=0.08 psi/ft Ceff=2.5 psi/ft Sliding friction: 0.65 Failure criterion = Mohr-Coulomb Tensional stregth =0 psi/ft 0.593 psi/ft 0.962 psi/ft Smax=0.75
- 29. Geomechanical model: Fault mechanism Anderson´s classification scheme for relative stress magnitudes in normal faulting regions. Earthquake focal mechanisms (right). Normal fault on borehole image log in a vertical well 0 1000 2000 3000 4000 5000 6000 7000 8000 0 2000 4000 6000 8000 10000 Depth(ft) Stress (psi) Hydrostatic Pp Shmin (MiniFrac) Pore Pressure (Model) Shmax Sv
- 30. Modeling natural fracture networks: Peña Negra Peña Negra Model
- 31. Source: Pozo, 2008 Source: Petrobras, 2008 Loss of circulation and fracture gradients
- 32. 1957 59 61 63 65 67 69 71 73 75 77 79 81 83 85 87 89 91 93 95 97 99 01 03 05 07 09 11 13 15 0.1 0.5 1 5 10 50 100 500 1000 FECHA LX.PetMOdc Completion EA1505 Completion EA1547 Completion EA1607 Completion EA1659 Completion EA1678 Completion EA1719 Completion EA1722 Completion EA1737 Completion EA1738 Completion EA1748 Completion EA1762 Completion EA1763 Completion EA1764 Completion EA1831 Completion EA1867 Completion EA1887 Completion EA1948 Completion EA2493 Completion EA5653D Completion EA5778 Completion EA5997 Completion EA6006 Completion EA6747 Completion EA7571EA1505 EA1547 EA1607 EA1659 EA1678 EA1719 EA1722 EA1737 EA1738 EA1748 EA1762 EA1763 EA1764 EA1831 EA1867 EA1887 EA1948 EA2493 EA5633 EA5653D EA5778 EA5997 EA6006 EA6747 EA7571 Abandonado Bombeo Mecanico Cerrado Temporario Suab por Csg Source: Escobedo, D. Connectivity of fractures - Peña Negra area
- 33. EA1618 EA1626 EA1647 EA1658 EA1674EA1718 EA1722 EA1748 EA1762 EA5651 EA5665 EA5782 EA8096D Bombeo Mecanico Suab por Tbg 1959 61 63 65 67 69 71 73 75 77 79 81 83 85 87 89 91 93 95 97 99 01 03 05 07 09 11 13 15 0.1 0.5 1 5 10 50 100 500 1000 FECHA LX.PetMOdc Completion EA1618 Completion EA1626 Completion EA1647 Completion EA1658 Completion EA1674 Completion EA1718 Completion EA1722 Completion EA1748 Completion EA1762 Completion EA5651 Completion EA5665 Completion EA5782 Completion EA8096D Connectivity of fractures - Peña Negra area Source: Escobedo, D.
- 34. -5000 -5000 CB-044CB-048 1505 1607 1659 1678 1719 1722 1737 17381748 1763 1764 1831 1867 1887 5633 5653D 5679 57785997 6006 6747 17627571 2493 1948 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 -9600-8800-8000-7200-6400-5600-4800 -9600-8800-8000-7200-6400-5600-4800 0.00 0.02 0.04 0.06 0.08 0.10 0.12 0.14 PHIEQ [ft3/ft3] 0 200 400 600m 472000 474000 472000 474000 952600095280009530000 952600095280009530000-5000 -5000 CB-044CB-048 1505 1607 1659 1678 1719 1722 1737 17381748 1763 1764 1831 1867 1887 5633 5653D 5679 57785997 6006 6747 17627571 2493 1948 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 -8800-8000-7200-6400-5600-4800-4000 -7500.000000 -7250.000000 -7000.000000 -6750.000000 -6500.000000 -6250.000000 -6000.000000 -5750.000000 -5500.000000 vation depth [ft] 0 200 400 600m F_Flood S/F_Distal_fan S_Mid_fan C_Proximal_fan Alluvial Facies 472000 474000 472000 474000 952600095280009530000 952600095280009530000 A Modelo estratigráfico - Estructural Modelo de electrofacies Modelo de porosidad A A’ Armazón estratigráfico-estructural 3D 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3 -8800-8000-7200-6400-5600-4800-4000 -7500.000000 -7250.000000 -7000.000000 -6750.000000 -6500.000000 -6250.000000 -6000.000000 -5750.000000 -5500.000000 Elevation depth [ft] 0 200 400 60 Chorro Sup. Chorro Inf. Fuente Medio Inferior Zonas -5000 CB-044CB-048 1505 1607 1659 1678 1719 1722 1737 17381748 1764 1831 1867 1887 5653D 5679 6006 6747 7571 2493 1948 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 -9600-8800-8000-7200-6400-5600-4800 -9600-8800-8000-7200-6400-5600-4800 0.00 0.02 0.04 0.06 0.08 0.10 0.12 0.14 PHIEQ [ft3/ft3] 0 200 400 600m 472000 474000 95280009530000 95280009530000 -5000 CB-044CB-048 1505 16591719 1722 1737 17381748 1764 1831 1867 1887 5653D 5679 6006 2493 1948 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 -8800-8000-7200-6400-5600-4800-4000 00000 00000 00000 00000 00000 00000 00000 00000 00000 depth [ft] 0 200 400 600m F_Flood S/F_Distal_fan S_Mid_fan C_Proximal_fan Alluvial Facies 472000 474000 95280009530000 95280009530000 A’ A A’ A A’ A A’ A A’ -5000 -5000 CB-044CB-048 1505 1607 1659 1678 1719 1722 1737 17381748 1763 1764 1831 1867 1887 5633 5653D 5679 57785997 6006 6747 17627571 2493 1948 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 -9600-8800-8000-7200-6400-5600-4800 -9600-8800-8000-7200-6400-5600-4800 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 Water saturation 0 200 400 600m 472000 474000 472000 474000 952600095280009530000 952600095280009530000 Modelo de Saturación A A’ A A’ -500 6 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 42 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 42 -9600-8800-8000-7200-6400-5600-4800 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 Water saturation 0 200 400 600m 4 95280009530000 Geological Model for Peña Negra area
- 35. Fracture sets characterization – Fractures in lithofacies
- 36. Fracture sets characterization – Fracture type classification
- 37. Fracture sets characterization – Fracture type classification
- 38. Fracture sets characterization – Fracture type & Intensity
- 39. Fracture sets characterization – Fracture type & Intensity
- 40. Fracture sets characterization – Geometry Lenght of fractures were determined from outcrops in Qda Salado. Fractures with great extent are mainly vertical to sub vertical. A power law was assumed. Mogollon Fm. in Qda Salado showing the geometry of the natural fractures
- 41. Fracture sets characterization – Aperture Apertures were measured in outcrops, cores and image logs. A log-normal distribution was given to the model.
- 42. Fracture sets characterization – Fracture Orientation
- 43. Modeling natural fracture networks Main Strike N50°E Main Dip angle 65° Main Strike N°50°E Main Dip angle 70° 1.83 mm 80 80 Moderate High Fracture parameter for modeling natural fracture networks 0.61 mm Fracture type model Characteristics Mean fracture density (#Fract/ft) Orientation Mean Length (m) Mean Aperture (mm) Facies with partially open fracture and moderate fracture density Facies with Open fractures and high fracture density 0.78 1.32
- 44. Modeling natural fracture networks
- 45. Modeling natural fracture networks - Upscaling
- 46. General Information: Fracture Sigma • Black-Oil Simulator Eclipse 100 • Cells = 30 x 52 x 46 • Average Dimensions = 100 m x 100 m x 50 ft • Total Cells = 68 850 • No Gas-Oil Contact • Water-Oil Contact = -7600 ft FRACTURE PARAMETERS • Aperture : 0.02 inches • Density: 0.2 frac per foot • Lenght : <25-180> foot • Orientation: 50° azimuth 65° dip Source: Escobedo, 2012 Numerical Reservoir Simulation
- 47. Validation of the reservoir model – History match for the whole model Initial history matching results for the Peña Negra model Initial Pressure, psi 3150 Current Pressure, psi 400 Cumulative Oil, MMBls 6.5275 Original Oil In Place, MMbls 18.65 Recovery Factor m+f, % 35%
- 48. Validation of the reservoir model – History match for one well in the model
- 49. Validation of the reservoir model – Oil left behind
- 50. The optimal well orientation – Critically stressed fractures Zoback, 2007
- 51. Nelson et.al. (2000) Discrete fracture network The optimal well orientation – Critically stressed fractures Shmax Data: 6100 ft – 7000ft N°_fractures: 210 Azimuth: 55.4° Average Dip: 53.5° τ>μσ Fractures close to failure are most likely to maintain permeability!!!
- 52. The optimal well orientation This methodology is being extrapolated to other parts of the block X, as in the field of Somatito where new drilling strategies are being proposed. Oriented well Fracture type zones model Discrete fracture network Peña Negra Model
- 53. q - 2015 q - 2024 q - 2035 cum - 2015 cum - 2024 cum - 2035 vertical 4,578 1,100 514 4,578 5,451,870 8,399,643 horizontal 7,141 1,063 349 7,141 6,600,234 9,065,511 ratio h/v 1.56 0.97 0.68 1.56 1.21 1.08 pozos vertical 3 3 3 3 3 3 pozos equiv 4.68 2.90 2.04 4.68 3.63 3.24 - 2.00 4.00 6.00 1 2 3 Series1 Numerical Reservoir Simulation – Horizontal well
- 54. Conclusions The construction of the natural fracture network model was validated by the simulation model. Fluid flows come mainly from natural fracture networks in Mogollon formation (Tight Sand Reservoir). Fractures are open in the direction of the least principal stress and align with the direction of the maximun horizontal stress. It is still possible to find undrained sets of fractures in the direction of the least principal stress and establish new development strategies. Possibility of drilling additional wells in order to obtain a larger contact area in these sets of fractures and to increase efficiency in the recovery within the reservoir.
- 55. THANK YOU FOR YOUR ATTENTION
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