Migration Trap Seal Mechanism Powerpoint MODIFIED
-
Upload
yashaasavi-raj-ladha -
Category
Documents
-
view
12 -
download
0
description
Transcript of Migration Trap Seal Mechanism Powerpoint MODIFIED
PLUNGING ANTICLINE IN THE KIMMERIDGE CLAY : Multibeam bathymetry image
Relationship of shale pore diameters to the molecular diameters of petroleum, with increasing depth of burial. At moderate depths of burial, shale pore diameters typically
become very small in relation to the larger petroleum molecules such as the asphaltenes.
• Micelles : molecules behaveing like soap, attach to a hydrocarbon molecule on one end and to an OH- at the other end.
• Can increase the amount of hydrocarbons transported by water.
• However, micelles are not found in rocks in sufficiently large quantities to explain most hydrocarbon accumulations.
A picture is worth a thousand words
Plane polarized transmitted light photomicrograph
Fluorescent microscopy showing well-connected horizontal microfracture network with submicroporous porosity
Bubble point line
Dew point line
Bulk volume of the cell Vbulk = L3
Number of spheres in the cell
n =(L/2r)3
Volume of the matrix Vmatrix = (4nπ r3)/3 = (L/2r)3 (4πr3)/3
= (π L3)/6 Porosity
DUAL POROSITY IN SANDSTONE
MATRIX
FRAMEWORK (QUARTZ)
FRAMEWORK (FELDSPAR)
CEMENT
PORE
Note different use of “matrix” by geologists and engineers
0.25 mm
Sandstone Comp. • Framework • Matrix • Cement • Pores
DISSOLUTION PORE
FRACTURE
1. Primary and secondary “matrix” porosity system 2. Fracture porosity system
SANDSTONE COMPOSITION, Framework Grains
Norphlet Sandstone, Offshore Alabama, USA Grains ~0.25 mm in Diameter/Length
PRF KF
P
KF = Potassium Feldspar PRF = Plutonic Rock Fragment
P = Pore Potassium Feldspar is Stained Yellow With a Chemical Dye
Pores are Impregnated With Blue-Dyed Epoxy
Q
Q = Quartz
Photo by R. Kugler
SECONDARY POROSITY: INTRAGRANULAR INEFFECTIVE
Scanning Electron Micrograph Tordillo Formation, Neuquen Basin, Argentina
Partially Dissolved Feldspar
Dissolution Pores may be Isolated and not contribute to the effective pore system
POROSITY IN SANDSTONE
Quartz Grain
Pore
Scanning Electron Micrograph Norphlet Sandstone, Offshore Alabama, USA
Porosity in Sandstone Typically is Lower Than That of Idealized Packed Spheres Owing to:
Variation in Grain Size Variation in Grain Shape Cementation Mechanical and Chemical Compaction
Photomicrograph by R.L. Kugler
POROSITY IN SANDSTONE
Scanning Electron Micrograph Tordillo Sandstone, Neuquen Basin, Argentina
Pore Throats in Sandstone May Be Lined With A Variety of Cement Minerals That Affect Petrophysical Properties
Photomicrograph by R.L. Kugler
POROSITY IN SANDSTONE
Scanning Electron Micrograph Norphlet Formation, Offshore Alabama, USA
Pores Provide the Volume to Store Hydrocarbons Pore Throats Restrict Flow through pores
Pore Throat
Secondary Electron Micrograph
Clay Minerals in Sandstone Reservoirs, Authigenic Chlorite
Jurassic Norphlet Sandstone Offshore Alabama, USA (Photograph by R.L. Kugler)
Occurs as Thin Coats on Detrital Grain Surfaces
Occurs in Several Deeply Buried Sandstones With High Reservoir Quality
Iron-Rich Varieties React With Acid
~ 10 µ m
Electron Photomicrograph
Clay Minerals in Sandstone Reservoirs, Fibrous Authigenic Illite
Jurassic Norphlet Sandstone Hatters Pond Field, Alabama, USA (Photograph by R.L. Kugler)
Illite
Significant Permeability Reduction
Negligible Porosity Reduction
Migration of Fines Problem
High Irreducible Water Saturation
INTERGRANULAR PORE AND MICROPOROSITY
Intergranular Pore
Microporosity
Kaolinite Quartz Detrital Grain
Intergranular Pores Contain Hydrocarbon Fluids
Micropores Contain Irreducible Water
Backscattered Electron Micrograph Carter Sandstone, Black Warrior Basin, Alabama, USA (Photograph by R.L. Kugler)
Clay Minerals in Sandstone Reservoirs, Authigenic Kaolinite
Secondary Electron Micrograph
Carter Sandstone North Blowhorn Creek Oil Unit Black Warrior Basin, Alabama, USA
Significant Permeability Reduction
High Irreducible Water Saturation
Migration of Fines Problem
(Photograph by R.L. Kugler)
PORE-SPACE CLASSIFICATION • Total porosity, φt =
• Effective porosity, φe =
VolumeBulkPore VolumeTotal
VolumeBulkPore SpacectedInterconne
• Effective porosity – of great importance;
contains the mobile fluid
COMPARISON OF TOTAL AND EFFECTIVE POROSITIES
• Very clean sandstones : φe → φt
• Poorly to moderately well -cemented intergranular materials: φt ≈ φe
• Highly cemented materials and most carbonates: φe < φt
Quartz(Framework) SmallPores IsolatedPoresLarge, InterconnectedPoresClay Surfaces& InterlayersClayLayers
Irreducible orImmobile WaterHydration orBound Water HydrocarbonPore VolumeStructural(OH ) Water
RockMatrix
Total Porosity - Neutron LogTotal Porosity - Density LogAbsolute or Total PorosityOven-Dried Core Analysis PorosityHumidity-DriedCore Analysis PorosityCapillaryWater
VShale
Sandstone Porosity Measuredby Various Techniques
(modified from Eslinger and Pevear, 1988)
Quartz(Framework) SmallPores IsolatedPoresLarge, InterconnectedPoresClay Surfaces& InterlayersClayLayers
Irreducible orImmobile WaterHydration orBound Water HydrocarbonPore VolumeStructural(OH ) Water
RockMatrix
Total Porosity - Neutron LogTotal Porosity - Density LogAbsolute or Total PorosityOven-Dried Core Analysis PorosityHumidity-DriedCore Analysis PorosityCapillaryWater
VShale
Sandstone Porosity Measuredby Various Techniques
(modified from Eslinger and Pevear, 1988)
SANDSTONE POROSITY MEASURED BY VARIOUS TECHNIQUES
Quartz (Framework)
Small Pores
Isolated Pores
Large, Interconnected Pores
Clay Surfaces & Interlayers
Clay Layers
Irreducible or Immobile Water
Hydration or Bound Water
Hydrocarbon Pore Volume
Structural (OH - ) Water
Rock Matrix
Total Porosity - Neutron Log Total Porosity - Density Log
Absolute or Total Porosity
Oven-Dried Core Analysis Porosity Humidity-Dried
Core Analysis Porosity
Capillary Water
V Shale
(modified from Eslinger and Pevear, 1988)
Carbonate porosity
Crystalline dolomite m = 1.95, φ = 47%, k = 3160 mD
Terrible uncertainty
K also Inverse of τ : Tortuosity (Total length/Mean path length)2
SV : Specific Surface Are (Area/ Rock volume)
Typical Specific Surface Areas
Material SV (cm-1)
Sand 80
Kaolinite (clay) 500
Smectite (clay) 1300
Illite (clay) 2800
Fundamental of CK eqn.:
Increased Surface area causes
increased flow resistance & Flow
Seperataion
• Permeability correlates inversely with
the clay content of sands.
• Sand > 35% clay Not Productive to oil
• Gamma ray log as good indicator of k
Reservoir Sandstone in 2-D Navajo Sandstone, porosity 13%, permeability ~200 mD
Real Rocks Are Three-Dimensional Pathways in 3-D are different from 2-D !
Pore Network of a Sandstone in 3-D Synchrotron tomography of sandstone.
Volume is one cubic millimeter and resolution 1 micrometer
Major Factors Affecting k
Typical occurrences of clay minerals in sandstones
Plot of decimal fraction of illite in I/S from shales in a typical well.
Individual points are sample measurements
The line is calculated from a burial history
Thermal history schematic showing integration of paleothermometers
Illite data constrain the burial or heating phase of a basin’s thermal history,
%R records maximum temperature, and apatite fission track analysis constrains timing of uplift and cooling
Illite and hydrocarbon exploration DAVID R. PEVEAR, Exxon Production Research, Proc. Natl. Acad. Sci. USA Vol. 96, pp. 3440–3446, March 1999
Laser fluorination is a specialised technique utilising a custom online preparation, extraction and purification system for the extraction of oxygen from silicate, oxide and clay minerals.
The technique is essential to release oxygen from these minerals and requires samples to be combusted in an atmosphere of either BrF5, ClF3 or F2
Zach Sharp all stainless steel line utilising BrF5 (Image courtesy of Dr. Zach Sharp)
Zach Sharp modified stainless steel and glass line utilising ClF3 (Image courtesy of Dr. Craig Barrie)
3-D Reservoir Architecture
Reservoir Connectivity
3-D Reservoir Shapes Map showing the initial production of wells in an oil Field. The contours follow almost precisely the isopach map of the net reservoir sands. What is the nature of this Reservoir: Way to avoid the dry wells (single dots outside the contoured areas)
F
γ Ө
r R
h Water
Oil
F = Upward force along contact γ = Surface tension cos Ө = F/γ Grav./Bouyancy force Total F = 2πr. γcos Ө = πr2 hρg Capillary force h= 2γcos Ө /rρg ρw – ρo Important
calcite
Quartz
University of Georgia Department of Geology GEOL 4320 Petroleum Geology
Shepherd 2009
σ1>σ2>σ3