The document summarizes the structural geology and tectonic development of the Delaware Basin and Central Basin Platform in West Texas and Southeastern New Mexico. It finds that the basins have a complex structure influenced by inherited rifting from 1.3-1.1 billion years ago. Movements during the Ancestral Rocky Mountains uplifts were accommodated along these preexisting weaknesses, resulting in geometries that do not align with expected patterns. Flexural subsidence in the Delaware Basin represents a superposition of profiles from the Central Basin Platform and Ouachita Mountains thrust belt. Interpretations of the basin's structure account for observed features and compare consistency.
This document discusses different well log measurements for determining porosity: sonic, density, and neutron logs. It provides details on how each log works, the parameters it measures, and how porosity can be derived from each log. A key point is that no single log directly measures porosity. By combining the logs, a more accurate estimate of porosity can be obtained by accounting for factors like lithology, fluid type, and borehole conditions. Secondary effects that can impact porosity calculations from each log are also reviewed.
During a period of erosion and sedimentation, grains of sediment are continuously building up on top of each other, generally in a water filled environment. As the thickness of the layer of sediment increases, the grains of the sediment are packed closer together, and some of the water is expelled from the pore spaces. However, if the pore throats through the sediment are interconnecting all the way to surface the pressure of the fluid at any depth in the sediment will be same as that which would be found in a simple colom of fluid. The pressure in the fluid in the pores of the sediment will only be dependent on the density of the fluid in the pore space and the depth of the pressure measurement (equal to the height of the colom of liquid). it will be independent of the pore size or pore throat geometry.
The document discusses the key components of a rotary drilling rig. It describes the major systems that make up a rig, including the power system, hoisting system, circulating system, rotary system, and well control system. For each system, it provides details on the important individual components, their functions, and how they work together to enable drilling operations. Key components discussed include the derrick, drawworks, kelly, drill pipe, blowout preventers, mud pumps, shale shakers, and other equipment used to hoist, rotate, circulate drilling fluid, and ensure well control.
Well log interpretation involves using well log data to estimate reservoir properties. It has been used since the 1920s to qualitatively identify hydrocarbons and is now a quantitative tool. A key figure was Gustavus Archie who in the 1940s established the field of petrophysics by relating well logs to core data. His work allowed properties like porosity, permeability and fluid saturation to be estimated. A presentation on well log interpretation outlined the workflow including editing logs, estimating properties like shale volume, porosity, permeability and fluid saturation, and presented two case studies analyzing different carbonate reservoirs.
1. The document discusses various well logging tools and concepts used in petrophysical interpretation. It describes tools such as the spontaneous potential (SP) log, gamma ray (GR) log, resistivity logs including induction and lateral logs, and porosity logs.
2. Key concepts covered include the logging environment and factors that impact tool measurements like borehole conditions and mud properties. Interpretation techniques for evaluating permeable zones, formation resistivity, water saturation, and porosity are also summarized.
3. The document provides examples of using tools and concepts like the Archie formula to calculate water resistivity, determine hydrocarbon presence, and evaluate clean versus shaly formations. It also discusses corrections that must be applied to well log
The document discusses seismic instrumentation used for gathering seismic data. It describes the main components - seismic sources, sensors, and acquisition systems. For seismic data acquisition, an elastic wavefield is emitted by a source and measured by receivers along lines or on a grid. The data is then processed and interpreted. The chapter focuses on the hardware used for seismic measurements, including discussions of airgun arrays as marine sources, vibroseis and dynamite for land sources, and geophones and hydrophones as sensors. It provides an overview of how the different components work together to generate seismic data.
A presentation of the acoustic waveform at a reservoir of a sonic or ultrasonic measurement, in which amplitude is present in the color or the shades of a gray scale. Variable –Density log is commonly used as an adjacent to cement bond log and offers better in sights in to its interpretations.
Acoustic waves are a type of longitudinal waves that propagate by means of adiabatic compression and decompression.
This document discusses porosity of reservoir rocks. It defines porosity as the ratio of pore volume to bulk volume of a rock. Porosity can be classified as original or induced. Factors that affect porosity include particle size, sorting, packing, cementation and stress. Porosity is important for reservoir engineering calculations as it represents the pore space occupied by fluids. It is measured through core analysis, well logging, or well testing. Laboratory methods to determine porosity include measuring bulk volume through fluid displacement or gravimetric techniques and pore volume through fluid saturation.
This document discusses different well log measurements for determining porosity: sonic, density, and neutron logs. It provides details on how each log works, the parameters it measures, and how porosity can be derived from each log. A key point is that no single log directly measures porosity. By combining the logs, a more accurate estimate of porosity can be obtained by accounting for factors like lithology, fluid type, and borehole conditions. Secondary effects that can impact porosity calculations from each log are also reviewed.
During a period of erosion and sedimentation, grains of sediment are continuously building up on top of each other, generally in a water filled environment. As the thickness of the layer of sediment increases, the grains of the sediment are packed closer together, and some of the water is expelled from the pore spaces. However, if the pore throats through the sediment are interconnecting all the way to surface the pressure of the fluid at any depth in the sediment will be same as that which would be found in a simple colom of fluid. The pressure in the fluid in the pores of the sediment will only be dependent on the density of the fluid in the pore space and the depth of the pressure measurement (equal to the height of the colom of liquid). it will be independent of the pore size or pore throat geometry.
The document discusses the key components of a rotary drilling rig. It describes the major systems that make up a rig, including the power system, hoisting system, circulating system, rotary system, and well control system. For each system, it provides details on the important individual components, their functions, and how they work together to enable drilling operations. Key components discussed include the derrick, drawworks, kelly, drill pipe, blowout preventers, mud pumps, shale shakers, and other equipment used to hoist, rotate, circulate drilling fluid, and ensure well control.
Well log interpretation involves using well log data to estimate reservoir properties. It has been used since the 1920s to qualitatively identify hydrocarbons and is now a quantitative tool. A key figure was Gustavus Archie who in the 1940s established the field of petrophysics by relating well logs to core data. His work allowed properties like porosity, permeability and fluid saturation to be estimated. A presentation on well log interpretation outlined the workflow including editing logs, estimating properties like shale volume, porosity, permeability and fluid saturation, and presented two case studies analyzing different carbonate reservoirs.
1. The document discusses various well logging tools and concepts used in petrophysical interpretation. It describes tools such as the spontaneous potential (SP) log, gamma ray (GR) log, resistivity logs including induction and lateral logs, and porosity logs.
2. Key concepts covered include the logging environment and factors that impact tool measurements like borehole conditions and mud properties. Interpretation techniques for evaluating permeable zones, formation resistivity, water saturation, and porosity are also summarized.
3. The document provides examples of using tools and concepts like the Archie formula to calculate water resistivity, determine hydrocarbon presence, and evaluate clean versus shaly formations. It also discusses corrections that must be applied to well log
The document discusses seismic instrumentation used for gathering seismic data. It describes the main components - seismic sources, sensors, and acquisition systems. For seismic data acquisition, an elastic wavefield is emitted by a source and measured by receivers along lines or on a grid. The data is then processed and interpreted. The chapter focuses on the hardware used for seismic measurements, including discussions of airgun arrays as marine sources, vibroseis and dynamite for land sources, and geophones and hydrophones as sensors. It provides an overview of how the different components work together to generate seismic data.
A presentation of the acoustic waveform at a reservoir of a sonic or ultrasonic measurement, in which amplitude is present in the color or the shades of a gray scale. Variable –Density log is commonly used as an adjacent to cement bond log and offers better in sights in to its interpretations.
Acoustic waves are a type of longitudinal waves that propagate by means of adiabatic compression and decompression.
This document discusses porosity of reservoir rocks. It defines porosity as the ratio of pore volume to bulk volume of a rock. Porosity can be classified as original or induced. Factors that affect porosity include particle size, sorting, packing, cementation and stress. Porosity is important for reservoir engineering calculations as it represents the pore space occupied by fluids. It is measured through core analysis, well logging, or well testing. Laboratory methods to determine porosity include measuring bulk volume through fluid displacement or gravimetric techniques and pore volume through fluid saturation.
This document discusses resistivity logs and how they are used to analyze borehole formations. Resistivity is measured in ohms per meter and depends on factors like water volume, temperature, and salinity. Resistivity logs can determine hydrocarbon versus water-bearing zones and indicate permeable zones. The Archie equation relates resistivity to water saturation and uses constants determined by rock type. Different resistivity tools like electrode and induction logs measure resistivity at varying depths around the borehole to analyze fluid content and identify zones.
This document provides procedures for well test operations. It describes various types of well tests including drawdown, build-up, and deliverability tests. It outlines responsibilities for company and contractor personnel involved in well testing. Safety barriers for well tests include well test fluid, mechanical barriers, casing overpressure valves, and more. Test string equipment, surface equipment, data acquisition methods, sampling procedures, and other well testing steps are also covered. The document aims to provide uniform guidelines for Agip's well testing operations worldwide.
The document discusses the basics of well logging design. It includes an agenda for a one-day course that covers basic logging theory, interpretation, logging program design, and a workshop. The objectives are to familiarize participants with various log measurements, well evaluation strategies, and approaches to well logging design. Key logging topics covered include definitions, history, measurement principles for resistivity, spontaneous potential, gamma ray, density, neutron, and acoustic logs. Interpretation applications and limitations are also discussed.
This document provides an overview of cement bond logging (CBL), which is a well logging technique used to evaluate the integrity of cement bonding between casing and borehole walls. It works by transmitting acoustic waves through the casing into the cement and detecting reflected signals to analyze bonding. Good cement bonding is indicated by low amplitude signals and strong formation reflections on the logs. CBL is important for assessing cement fill quality, casing integrity, and identifying potential fluid migration paths. It provides a cost-effective way to evaluate cementing operations and design remediation if needed.
The document discusses the functions and types of casing strings used in oil and gas wells. It describes the different casing strings like conductor casing, surface casing, intermediate casing, and production casing. It also covers casing design criteria like classifications based on outside diameter, length, connections, weight, and grade. The mechanical properties of casing are discussed in relation to withstanding tensile, burst, and collapse loads during drilling and production operations.
1. The document discusses magnetic methods for groundwater exploration. It covers topics such as the earth's magnetic field, magnetization of materials, magnetic anomalies over simple shapes, and magnetic surveying.
2. Key points include that magnetic surveying measures variations in the magnetic field to locate concentrations of magnetic materials. The magnetic susceptibility of rocks can vary significantly and influences the induced magnetization. Magnetic anomalies provide information on the location, size, and depth of magnetic sources like dykes.
3. Temporal variations in the earth's magnetic field like diurnal and secular changes need to be considered during data acquisition and processing to accurately interpret magnetic survey results.
Quantitative and Qualitative Seismic Interpretation of Seismic Data Haseeb Ahmed
This document discusses quantitative and qualitative seismic interpretation techniques used to analyze seismic data and map subsurface geology. It compares traditional qualitative techniques to more modern quantitative techniques. It then focuses on unconventional seismic interpretation techniques used for unconventional reservoirs with low permeability, including AVO analysis, seismic inversion, seismic attributes, and forward seismic modeling. These techniques can help identify tight gas, shale gas, and gas hydrate reservoirs that conventional methods cannot easily detect. The document provides details on how each technique works and its advantages.
A drill stem test (DST) is used to test characteristics of a newly drilled well while the drilling rig is still on site. It can provide estimates of permeability, reservoir pressure, fluid types, wellbore damage, barriers and fluid contacts. There are three main methods to analyze DST data: Horner's plot method, type curve matching method, and computer matching. Type curve matching involves matching pressure change over time data from the DST to standard type curves to determine properties like permeability and skin factor. Gringarten type curves are commonly used and account for variations in pressure over time based on reservoir-well configurations.
Day 2 d coring & core analysis and reservoir geologyDr. Arzu Javadova
This document discusses core laboratory processing and analysis techniques. It covers topics such as core receipt and cutting, CT scanning, gamma ray logging, plugging, slabbing, photography, and special handling considerations for difficult rock types like unconsolidated cores, carbonates, and shales. It provides details on various core analysis techniques and recommendations to minimize core damage during handling and transportation.
Slide1:
Seismic Sources
HOW TO GENERATE SEISMIC WAVES?
Exploration seismology – mostly artificial sources
à active technique
Natural sources can also be used (e.g. earthquakes) – usually
for tectonic studies (passive seismic exploration)
!
What is a good source?
- economical, efficient, convenient
- safe and environmentally acceptable
- sufficient energy over the suitable frequency range
- repeatable
Slide 2:
Land seismic sources
Explosives: - usually detonated in boreholes or buried
PROS
- sharp, impulsive, high amplitude (mostly P-wave)
- reasonably cheap
CONS
- The signal is not repeatable
- slow (borehole drilling)
- can be destructive
Anderson's theory of faulting predicts that the orientation of faults depends on the principal stresses. It assumes reverse faults dip at 30 degrees, normal faults dip at 60 degrees, and strike-slip faults are vertical. However, exceptions like low-angle normal faults exist. Pore fluid pressure or pre-existing weaknesses in the rock can allow faults to form at shallower angles. The rolling-hinge model also explains how low-angle normal faults can develop.
This is an academic lecture for Diploma in Engineering 7th Semester Mining and Mine Survey Technology. The Course related to this presentation is Basic of well planning.
The document provides an overview of bond log theory, interpretation, and applications including how acoustic bond logs work, what different measurements indicate, examples of good and poor cement bonds, considerations for scenarios like channeled cement or microannuli, and examples of bond log use for integrity evaluation in steam injection wells. Key topics covered include the purposes of cement, when bond logs are run, traditional acoustic bond tool components and measurements, factors that affect bond logs, and media coverage of oil industry environmental issues.
The document discusses caliper well logs, which measure the diameter and shape of boreholes. It describes how caliper tools work, including mechanical calipers with extendable arms that measure variations in borehole diameter. Common types are 2-arm, 4-arm, and ultrasonic calipers. Caliper logs present continuous borehole diameter measurements and are used to make environmental corrections to other well logs and assess lithology, permeability, and porosity.
The resistivity log measures the ability of rock formations to conduct electricity. Higher resistivity indicates water-bearing zones while lower resistivity corresponds to hydrocarbon-bearing zones. Resistivity is dependent on factors like porosity, fluid salinity, and lithology. Resistivity logs are used to identify hydrocarbon zones, permeable layers, and estimate porosity. Log interpretation provides values for parameters like porosity, water saturation, and lithology which can then be used to calculate reserves and map reservoir characteristics.
What is the different between the net pay and resrvoir thicknessStudent
Prepared by Yasir Albeatiy
Contact me with information below:
E-Mail: yasiralbeatiy2015@gmail.com
Phone No. + Whatsapp : +9647828319225
Facebook Page: www.facebook.com/petroleumengineeringz
This document provides an overview of petroleum drilling fundamentals, including different types of rigs used for offshore drilling. It discusses jack-up rigs, semi-submersible rigs, drill ships, condeep platforms, jacket platforms, and tension leg platforms. It also covers well planning, designing the well, drilling operations, completions, new technologies, and structural geology. Key steps in drilling include obtaining licenses, exploration, appraisal, development, maintenance, and abandonment of oil and gas fields. Safety and monitoring drilling progress are also emphasized.
Here are the steps to solve these problems:
1) T at 5000 ft depth = Ts + αD
= 75 + 1.5(5000/100)
= 75 + 75
= 150 F
2) Geothermal gradient = (T2 - T1)/D2 - D1)
= (122 - 80)/2200
= 1.5 °F/100ft
So the geothermal gradient of the sandstone layer is 1.5 °F/100ft.
This document outlines the key steps in a simple seismic data processing workflow, including: data initialization such as reformatting, geometry updates, and trace editing; amplitude processing; noise attenuation; deconvolution; multiple attenuation; velocity analysis and NMO; migration; stacking; and data makeup. Each processing step is briefly described and examples are provided of before and after visualizations. References and an opportunity for questions are provided at the end.
production Bone Spring-Wolfcamp vs other resource plays.pptJerry Beets
The document contains various charts and data about oil and gas production, costs, and forecasts in major North American shale plays such as the Permian Basin, focusing on the Delaware Basin, Midland Basin, and Wolfcamp and Bone Spring formations. Metrics discussed include lateral lengths, proppant usage, well costs, production rates, break-even prices, rig counts, permits, drilled uncompleted wells, and forecasts for production and prices out to 2040. Recent acquisition costs in the Delaware and Midland basins are also mentioned.
Bert Vandiver attended Baylor University, where he earned his bachelor of business administration in marketing and management. Today, as founder and CEO of LR Commercial Construction, Inc., Bert Vandiver develops fossil-fuel pipeline projects throughout the Permian Basin.
This document discusses resistivity logs and how they are used to analyze borehole formations. Resistivity is measured in ohms per meter and depends on factors like water volume, temperature, and salinity. Resistivity logs can determine hydrocarbon versus water-bearing zones and indicate permeable zones. The Archie equation relates resistivity to water saturation and uses constants determined by rock type. Different resistivity tools like electrode and induction logs measure resistivity at varying depths around the borehole to analyze fluid content and identify zones.
This document provides procedures for well test operations. It describes various types of well tests including drawdown, build-up, and deliverability tests. It outlines responsibilities for company and contractor personnel involved in well testing. Safety barriers for well tests include well test fluid, mechanical barriers, casing overpressure valves, and more. Test string equipment, surface equipment, data acquisition methods, sampling procedures, and other well testing steps are also covered. The document aims to provide uniform guidelines for Agip's well testing operations worldwide.
The document discusses the basics of well logging design. It includes an agenda for a one-day course that covers basic logging theory, interpretation, logging program design, and a workshop. The objectives are to familiarize participants with various log measurements, well evaluation strategies, and approaches to well logging design. Key logging topics covered include definitions, history, measurement principles for resistivity, spontaneous potential, gamma ray, density, neutron, and acoustic logs. Interpretation applications and limitations are also discussed.
This document provides an overview of cement bond logging (CBL), which is a well logging technique used to evaluate the integrity of cement bonding between casing and borehole walls. It works by transmitting acoustic waves through the casing into the cement and detecting reflected signals to analyze bonding. Good cement bonding is indicated by low amplitude signals and strong formation reflections on the logs. CBL is important for assessing cement fill quality, casing integrity, and identifying potential fluid migration paths. It provides a cost-effective way to evaluate cementing operations and design remediation if needed.
The document discusses the functions and types of casing strings used in oil and gas wells. It describes the different casing strings like conductor casing, surface casing, intermediate casing, and production casing. It also covers casing design criteria like classifications based on outside diameter, length, connections, weight, and grade. The mechanical properties of casing are discussed in relation to withstanding tensile, burst, and collapse loads during drilling and production operations.
1. The document discusses magnetic methods for groundwater exploration. It covers topics such as the earth's magnetic field, magnetization of materials, magnetic anomalies over simple shapes, and magnetic surveying.
2. Key points include that magnetic surveying measures variations in the magnetic field to locate concentrations of magnetic materials. The magnetic susceptibility of rocks can vary significantly and influences the induced magnetization. Magnetic anomalies provide information on the location, size, and depth of magnetic sources like dykes.
3. Temporal variations in the earth's magnetic field like diurnal and secular changes need to be considered during data acquisition and processing to accurately interpret magnetic survey results.
Quantitative and Qualitative Seismic Interpretation of Seismic Data Haseeb Ahmed
This document discusses quantitative and qualitative seismic interpretation techniques used to analyze seismic data and map subsurface geology. It compares traditional qualitative techniques to more modern quantitative techniques. It then focuses on unconventional seismic interpretation techniques used for unconventional reservoirs with low permeability, including AVO analysis, seismic inversion, seismic attributes, and forward seismic modeling. These techniques can help identify tight gas, shale gas, and gas hydrate reservoirs that conventional methods cannot easily detect. The document provides details on how each technique works and its advantages.
A drill stem test (DST) is used to test characteristics of a newly drilled well while the drilling rig is still on site. It can provide estimates of permeability, reservoir pressure, fluid types, wellbore damage, barriers and fluid contacts. There are three main methods to analyze DST data: Horner's plot method, type curve matching method, and computer matching. Type curve matching involves matching pressure change over time data from the DST to standard type curves to determine properties like permeability and skin factor. Gringarten type curves are commonly used and account for variations in pressure over time based on reservoir-well configurations.
Day 2 d coring & core analysis and reservoir geologyDr. Arzu Javadova
This document discusses core laboratory processing and analysis techniques. It covers topics such as core receipt and cutting, CT scanning, gamma ray logging, plugging, slabbing, photography, and special handling considerations for difficult rock types like unconsolidated cores, carbonates, and shales. It provides details on various core analysis techniques and recommendations to minimize core damage during handling and transportation.
Slide1:
Seismic Sources
HOW TO GENERATE SEISMIC WAVES?
Exploration seismology – mostly artificial sources
à active technique
Natural sources can also be used (e.g. earthquakes) – usually
for tectonic studies (passive seismic exploration)
!
What is a good source?
- economical, efficient, convenient
- safe and environmentally acceptable
- sufficient energy over the suitable frequency range
- repeatable
Slide 2:
Land seismic sources
Explosives: - usually detonated in boreholes or buried
PROS
- sharp, impulsive, high amplitude (mostly P-wave)
- reasonably cheap
CONS
- The signal is not repeatable
- slow (borehole drilling)
- can be destructive
Anderson's theory of faulting predicts that the orientation of faults depends on the principal stresses. It assumes reverse faults dip at 30 degrees, normal faults dip at 60 degrees, and strike-slip faults are vertical. However, exceptions like low-angle normal faults exist. Pore fluid pressure or pre-existing weaknesses in the rock can allow faults to form at shallower angles. The rolling-hinge model also explains how low-angle normal faults can develop.
This is an academic lecture for Diploma in Engineering 7th Semester Mining and Mine Survey Technology. The Course related to this presentation is Basic of well planning.
The document provides an overview of bond log theory, interpretation, and applications including how acoustic bond logs work, what different measurements indicate, examples of good and poor cement bonds, considerations for scenarios like channeled cement or microannuli, and examples of bond log use for integrity evaluation in steam injection wells. Key topics covered include the purposes of cement, when bond logs are run, traditional acoustic bond tool components and measurements, factors that affect bond logs, and media coverage of oil industry environmental issues.
The document discusses caliper well logs, which measure the diameter and shape of boreholes. It describes how caliper tools work, including mechanical calipers with extendable arms that measure variations in borehole diameter. Common types are 2-arm, 4-arm, and ultrasonic calipers. Caliper logs present continuous borehole diameter measurements and are used to make environmental corrections to other well logs and assess lithology, permeability, and porosity.
The resistivity log measures the ability of rock formations to conduct electricity. Higher resistivity indicates water-bearing zones while lower resistivity corresponds to hydrocarbon-bearing zones. Resistivity is dependent on factors like porosity, fluid salinity, and lithology. Resistivity logs are used to identify hydrocarbon zones, permeable layers, and estimate porosity. Log interpretation provides values for parameters like porosity, water saturation, and lithology which can then be used to calculate reserves and map reservoir characteristics.
What is the different between the net pay and resrvoir thicknessStudent
Prepared by Yasir Albeatiy
Contact me with information below:
E-Mail: yasiralbeatiy2015@gmail.com
Phone No. + Whatsapp : +9647828319225
Facebook Page: www.facebook.com/petroleumengineeringz
This document provides an overview of petroleum drilling fundamentals, including different types of rigs used for offshore drilling. It discusses jack-up rigs, semi-submersible rigs, drill ships, condeep platforms, jacket platforms, and tension leg platforms. It also covers well planning, designing the well, drilling operations, completions, new technologies, and structural geology. Key steps in drilling include obtaining licenses, exploration, appraisal, development, maintenance, and abandonment of oil and gas fields. Safety and monitoring drilling progress are also emphasized.
Here are the steps to solve these problems:
1) T at 5000 ft depth = Ts + αD
= 75 + 1.5(5000/100)
= 75 + 75
= 150 F
2) Geothermal gradient = (T2 - T1)/D2 - D1)
= (122 - 80)/2200
= 1.5 °F/100ft
So the geothermal gradient of the sandstone layer is 1.5 °F/100ft.
This document outlines the key steps in a simple seismic data processing workflow, including: data initialization such as reformatting, geometry updates, and trace editing; amplitude processing; noise attenuation; deconvolution; multiple attenuation; velocity analysis and NMO; migration; stacking; and data makeup. Each processing step is briefly described and examples are provided of before and after visualizations. References and an opportunity for questions are provided at the end.
production Bone Spring-Wolfcamp vs other resource plays.pptJerry Beets
The document contains various charts and data about oil and gas production, costs, and forecasts in major North American shale plays such as the Permian Basin, focusing on the Delaware Basin, Midland Basin, and Wolfcamp and Bone Spring formations. Metrics discussed include lateral lengths, proppant usage, well costs, production rates, break-even prices, rig counts, permits, drilled uncompleted wells, and forecasts for production and prices out to 2040. Recent acquisition costs in the Delaware and Midland basins are also mentioned.
Bert Vandiver attended Baylor University, where he earned his bachelor of business administration in marketing and management. Today, as founder and CEO of LR Commercial Construction, Inc., Bert Vandiver develops fossil-fuel pipeline projects throughout the Permian Basin.
Permian Delaware and Midland basins play.pptJerry Beets
The document discusses the geology and production of the Permian Basin across the Midland and Delaware Basins. It covers the stratigraphy, depositional systems, structure, productive areas, key formations like the Wolfcamp and Bone Spring, resource play polygons, and production type curves. Maps show attributes like thickness, porosity, gas-oil ratios, and acreage ownership across the Permian Basin provinces in Texas.
Shale gas downstream investment $164 bbSteve Wittrig
The document summarizes the significant investment and growth in the US chemical industry due to increased shale gas production. It notes that $164 billion has been announced in potential investment as of April 2016, with 40% completed or underway and 55% in planning. This investment is creating a large cost advantage for the US chemical industry over other regions. It also describes the economic benefits expected from this investment and growth, including over 700,000 new permanent jobs and $301 billion in additional annual economic output by 2023.
Apache Alpine High 2016 0907 barclays-ir_presentationSteve Wittrig
John Christmann, CEO and President of Apache Corporation, presented at the Barclays CEO Energy-Power Conference on September 7, 2016. He discussed Apache's corporate strategy, focusing on operational flexibility, growth from unconventional assets in North America, and generating cash flow from international and conventional assets. Christmann also provided updates on Apache's Permian Basin position, highlighting over 1.75 million net acres across key regions including the Midland and Delaware Basins, with recent well results outperforming type curves.
The document summarizes an upcoming conference on using geological and geophysical data to optimize drilling and completions strategies in unconventional plays in the Permian Basin. The two-day conference in Houston, Texas will feature over 20 expert speakers from leading Permian Basin energy companies. Day one will focus on using data to optimize strategies in key plays like the Wolfcamp, Bone Spring, and Spraberry formations. Day two will focus on using well logs, core samples, and reservoir data to improve productivity. Topics will include seismic analysis, mapping faults and fractures, geosteering, and integrating petrophysical properties to predict productivity.
The document summarizes key information about the Permian Basin, including its structural setting, drilling zones, and potential. It describes how the basin was formed through uplifts and subsidence, filling with thick Paleozoic sediments containing oil and gas reservoirs. Traditionally carbonates dominated production, but unconventional techniques now exploit lower permeability shale and tight sand reservoirs, transforming the basin into a shale development hotspot. Drilling often accesses multiple stacked pay zones from a single well, enhancing economics. Significant potential remains through infill drilling and developing unconventional plays.
Bone Spring 2 porosity distribution in Lea Co New Mexico.pdfJerry Beets
The document discusses the Permian paleogeography and stratigraphy of the Delaware Basin in New Mexico. It analyzes porosity log data from the Bone Spring 2 formation which indicates thicker zones of higher porosity oriented in a NE-SW direction, suggesting deposition from channels sourced from structural highlands to the north, east and west. Core data shows higher porosity corresponds to higher permeability. Mapping porosity trends can help define production sweet spots and maximize the economic potential of the Bone Spring 2 play.
Map showing the counties located in the Delaware River Basin and therefore (unfortunately) subject to the Delaware River Basin Commission's years-long and ongoing moratorium on Marcellus Shale drilling. It is a particuarly onerous moratorium for those living in Pennsylvania counties like Wayne and Pike in northeastern PA where there is a lot of drilling activity. Those landowners have been and continue to be screwed by not allowing drilling.
This document provides an overview of Morgan Stanley's presentation on EnLink Midstream at the Permian Basin Energy Summit on April 1, 2014. It discusses EnLink Midstream's strategic assets across multiple regions, its diverse fee-based cash flows primarily from long-term contracts with Devon Energy, and its growth strategy through organic projects, dropdowns from Devon, serving third parties, and acquisitions. The presentation also highlights EnLink Midstream's investment attributes including its scale, financial strength, management team, and sponsor support from Devon Energy.
This document provides an overview of structural geology and geologic map interpretation. It discusses key topics such as rock deformation, folding, faulting, joints, continental tectonic landform units, and the geomorphology of folded terrain. Specifically, it describes how rocks can deform through plastic, elastic, or brittle mechanisms in response to stress. It also explains different types of folds and faults that form due to compression and tension. The relationships between rock structures, erosion rates, and resulting landforms are explored.
This document is the 2009 revision of the Geological Society of America Rock-Color Chart, which provides color chips to aid in describing rock colors. It notes that the chart covers the typical range of colors seen in rocks and recommends replacing the chart every two years to maintain consistent color references over time. The document provides instructions on using the chart for different grain sizes and wet vs dry rocks, and notes the chart is designed primarily for field use in rock color identification.
Mercer Capital's Value Focus: Exploration and Production | Q2 2016Mercer Capital
Mercer Capital's Energy Industry newsletter provides perspective on valuation issues. Each newsletter also typically includes macroeconomic trends, industry trends, and guideline public company metrics.
This document provides an overview of recruitment in the oil and gas industry, including:
- Definitions of the upstream, midstream, and downstream sectors.
- The differences between service companies and operators.
- The types of jobs available based on degree level, from BS to PhD.
- An overview of recruiting companies that visited the University of Houston in 2014.
- Tips for resume writing, interviewing, and networking to help secure a position in the oil and gas industry.
Unconventional Wells not yet completed.pptJerry Beets
The document contains details of over 40 wells including their API number, operator, lease name, well number, location, and target formation. The majority of wells listed are located in sections 25-33S and ranges 32-34E targeting the Avalon, Bone Spring, and Wolfcamp formations with operators including BTA and Texaco.
1) The document identifies 5 different rocks: slate, sandstone (identified for 3 different rocks), and pumice.
2) For each rock, the document describes the texture, color, and sometimes location where the rock was found to help identify what type of rock it is.
3) Additional context is provided about the geological background of the Santa Monica Mountains and areas around Pyramid Lake where some of the rocks were discovered.
The document provides guidance on describing clastic cuttings from drilling operations. It outlines 12 aspects that should be included in a cutting description, in a specific order: 1) rock type, 2) colour, 3) hardness, 4) fracture and texture, 5) grain size, 6) sorting, 7) angularity/roundness, 8) sphericity, 9) matrix, 10) cementation, 11) accessories and fossils, 12) porosity, and 13) hydrocarbon indications. Descriptions of arenaceous and argillaceous rocks are also provided, along with guidelines on determining lithology, colour, hardness, texture, and other characteristics. Proper terminology and methods for accurate cutting descriptions are emphasized
Metamorphic rocks are rocks that have changed from one type to another due to high heat and pressure underground over millions of years. This process of metamorphism can change a rock's texture, chemical composition, and internal structure. Jade rock specifically forms where tectonic plates meet in areas with high underground heat and pressure, as this environment transforms pyroxene rock into crystalline jade over long periods of time.
1. The study uses regional gravity anomalies to identify magmatic structures beneath Medicine Lake volcano in northeastern California.
2. Gravity models find positive anomalies correspond to denser rocks while negative anomalies correspond to less dense rocks.
3. The best-fitting gravity model incorporates data on surficial geology, magnetotellurics readings, and seismic velocities, supporting the presence of multiple composition magma chambers as well as an impermeable smectite clay cap.
4. The models indicate rhyolite, basalt, and andesite magma chambers at depths consistent with previous seismic data, helping explain the volcano's varying eruptive compositions over the last 500,000 years.
1) The document describes the creation of a geodatabase for Mount Jefferson in Oregon to better understand its volcanic, tectonic, and glacial history and address a lack of geologic data for the central Oregon Cascades.
2) The geodatabase includes shapefiles, attribution data, and over 1,000 geochemical analyses that can be used to model the volcano's evolution and estimate eruptive conditions from thermobarometry experiments.
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This document discusses the geological and tectonic settings of the Palk Bay-Gulf of Mannar area between India and Sri Lanka and their relevance to the Sethu Samudram Shipping Canal Project. The region contains hard igneous and metamorphic rocks inland with sedimentary rocks in coastal and offshore areas, arranged in a series of basins and ridges oriented NNE-SSW, N-S, and E-W. Geophysical data shows corresponding gravity, magnetic, and structural features. The area experiences movement along four fault systems oriented NNE-SSW, NW-SE, N-S, and E-W, which have been reactivated recently, indicating neo-tectonic activity. This includes strike-
Using sea-floor morphometrics to constrain stratigraphic models of sinuous su...Aaron Reimchen
Constructing geologically accurate reservoir models of deep-water strata is challenging due to the reliance
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Discrete Fracture Network Simulation for Sedimentary Enhanced Geothermal Syst...Caitlin Hartig
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2. Limited data on natural fractures required assumptions that surface lineaments reflect the orientation and location of fractures based on stress regime analysis.
3. A DFN simulation was constructed under these assumptions to facilitate reservoir modeling and evaluation of the feasibility of a sedimentary enhanced geothermal system in this location.
1) The document evaluates the thrusting and folding of the Deadman Creek Thrust Fault in the Sangre de Cristo Range in southern Colorado.
2) The Deadman Creek Thrust Fault emplaced older rock over younger rock during the Laramide Orogeny, and was later folded by continued compression to form the Pole Creek Anticline.
3) Stereonet plots and cross-sections show the anticline is an overturned isoclinal fold that becomes more vertical to the northwest, with apparent normal faulting on the overturned forelimb reflecting out-of-syncline thrust faulting.
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2) Continued deformation resulted in the folding of the Deadman Creek Thrust Fault to form the overturned Pole Creek Anticline, a northeast-verging fold.
3) The driving force behind the folding of the Pole Creek Anticline was a propagating reverse fault that caused the Deadman Creek Thrust Fault to fold, though the structural geology of the area is complex with additional minor faults present.
This document describes methods used to enhance seismic data processing and interpretation of fracture zones in the granitic basement of the Cuu Long Basin in Vietnam. Multiple attenuation filters including f-k, Tau-P and Radon transforms were used to remove noise and multiples, improving the signal-to-noise ratio. Kirchhoff migration and Controlled Beam Migration were applied to better image steeply dipping faults and fractures. Seismic attributes like curvature, apparent dip and energy gradient helped further locate and map faults and fractures to delineate potential hydrocarbon reservoirs. The enhanced seismic data processing and interpretation techniques improved imaging of the complex fractured basement, aiding exploration.
3D Inversion & Negative Inversional Fault Systems, Taranaki Basin, Offshore NZ Isaac Kenyon
This is my final MSc Petroleum Geoscience Presentation to academics and professionals at the Royal Holloway University annual MSc Petroleum Geoscience Symposium.
The document discusses a project to synthesize regional geophysical, geochemical, and geological models of the crust and upper mantle. The researcher is loading various datasets into 3D modeling software, including seismic reflection data, tomographic models, and potential field data. Some challenges with legacy seismic data and model resolution are noted. The goal is to co-render the different datasets to gain new insights into crustal evolution by relating geophysics, geology, and geochemistry at both large and small scales. Future work involves incorporating additional seismic, tomographic, and geochemical datasets.
This article presents a workflow for predicting time-lapse stress effects in seismic data due to production-induced stress changes. The workflow involves building reservoir and geomechanical models, dynamically modeling fluid flow and reservoir compaction over time, calculating changes in elastic properties from stress changes, and using these to predict changes in seismic attributes. The workflow is demonstrated on a synthetic double-dipping anticline reservoir model. Modeling predicts vertical and horizontal subsurface displacement, changes in triaxial stress state in the overburden, and time-lapse changes up to 40ms in seismic attributes like P-wave and S-wave travel times that could be observed in field seismic data.
18494_Guided Facies Modeling using 3D Seismic and WellRoy Cox
This document summarizes research using 3D seismic data and well logs to create more geologically realistic models of reservoir facies distributions. Seismic attribute images were interpreted to map fluvial depositional features like channels. These geomorphic objects were then used to guide facies modeling between wells. This "soft conditioning" approach produced models that better honored both well data and seismic trends compared to previous methods. It was applied to reservoirs in the BB oil field comprised of Miocene fluvial and coastal deposits. Seismic slices helped delineate multiple channel belts and a point bar complex that informed the final facies models.
This document summarizes a hydrogeophysical investigation using self-potential and resistivity surveys at Hidden Dam in California to better understand seepage patterns and subsurface geology. 512 self-potential measurements identified known seepage areas and a potential new area, while two 2,500 foot resistivity profiles indicated a sediment channel that may be a significant seepage pathway. Numerical modeling of subsurface flow correlated with geophysical data and confirmed a focusing of seepage in low-lying areas downstream, consistent with past observations. The integrated approach provides a framework for improved understanding of seepage conditions at the site.
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- Field mapping revealed thick sequences of Belt Supergroup rocks formed basement culminations in the wedge, while further southwest large magmatic plutons replaced the basement highs. Around 75 million years ago, increased magmatism marked a major change in crustal rheology.
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The document discusses lessons that can be learned from the South Atlantic basin and applied to exploration in the North Atlantic basin. It summarizes that fracture zones in the South Atlantic influenced continental and oceanic crust morphology, hydrocarbon migration, and led to complex trap geometries from reactivation. Similarly, fracture zones are recognized in the North Atlantic and likely influenced structural development. New exploration concepts can be developed for the North Atlantic by considering this model of conjugate margins and fracture zone influence from the South Atlantic.
This document provides a geological survey of the Buttston 7.5-minute Quadrangle in central Tallapoosa County, Alabama. It summarizes the geology, physiography, and previous studies of the area. Key findings include that the quadrangle encompasses rocks from the eastern Blue Ridge, the Brevard fault zone, and the Inner Piedmont. The Brevard fault zone contains the Jacksons Gap Group and marks a fundamental fault in Appalachian geology. Detailed mapping was needed due to development along highways and proximity to reservoirs.
This document provides a summary of a geological survey of the Buttston 7.5-minute Quadrangle in Tallapoosa County, Alabama. The key findings are that the Brevard fault zone lithologies in this area are difficult to separate into distinct map units due to gradational contacts. Structures related to the D1 metamorphic event are truncated by the Katy Creek fault, while D1-D2 structures appear undisrupted. Plastic deformation during the D2 event created mylonitic fabrics along the Abanda fault. Cataclasite zones along the Abanda fault mark the final brittle movement during the breakup of Pangea. The survey aims to better understand the geology and address questions about
This document provides a summary of a geological survey of the Buttston 7.5-minute Quadrangle in Tallapoosa County, Alabama. The key findings are that the Brevard fault zone lithologies in this area are difficult to separate into distinct map units due to gradational contacts. Structures related to the D1 Neoacadian metamorphism are truncated by the Katy Creek fault, while D1-D2 structures are undisrupted. Plastic deformation during the D2 Alleghanian event created mylonitic textures along the Abanda fault. Cataclasite zones along the Abanda fault mark the final brittle movement during the Mesozoic rifting of Pangea. The
Similar to Delaware Basin Structural Relationships_Manos (20)
1. BERG - HUGHES
C E N T E R
Structural Relationships of the Delaware Basin
and Central Basin Platform
Telemachos A. Manos
2. BERG - HUGHES
C E N T E R
Conclusions
Basin Layout
A complex interplay of structural elements giving it the geometries we
observe.
Related to Ancestral Rocky Mountain uplifts, but the geometries do not align
with what we would expect for Marathon Orogeny
Inherited structures
Permian Basin has a history of rifting which influences later movements
Arrangement and trend of features might not align with ‘ideal’ structural
geometries for later events. Tectonic movements are reactivated on
preexisting planes of weakness
Flexural Profile
Superposition of two foreland basin profiles.
Possibility of heterogeneity in the flexural rigidity.
Two Interpretations
Development of structure accounting for observed features.
Comparing consistency of interpretations
3. BERG - HUGHES
C E N T E R
Uplift
Depression
Fold-Thrust Belt
Modified from Anthony (2015)
• West Platform Fault - Contact
between DB and CBP
• Timing and orientation of CBP
uplift similar to that of other
Ancestral Rocky Mountain
Uplifts.
• Orientation of E/W compression
does not agree with NW
advancement of OMTB
Tectonic Stresses
4. BERG - HUGHES
C E N T E R
A A’
Complex structures on the CBP margin.
Thrust, normal, and strike slip faulting.
Hills (1984)
5. BERG - HUGHES
C E N T E R
Many of the features in the Permian Basin are inherited from prior
rifting, and persist throughout basin development.
Whitmeyer & Karlstrom (2007)
6. BERG - HUGHES
C E N T E R
Shumaker (1992), Galley (1958)
• After Grenville Mid-continent rifting in (A), several yoked
‘sag basins’ were superimposed after breakup of
Rhodinia (B). Timing and orientation similar to that of the
Southern Oklahoma Aulacogen.
• Igneous basement in DB dated to 1.3-1.1 Ga, suggesting
dominant structural rifting in Grenville, and minimum
structural influence in Rhodinia breakup.
• Unit thicknesses of Tobosa Basin indicate timing and
amount of sag post-breakup.
7. BERG - HUGHES
C E N T E R
• Delaware Aulacogen is similar in trend and timing to other Rhodinia-breakup
related Aulacogens.
• Predetermined planes of weaknesses reactivated during Ancestral Rocky
Mountain uplifts.
Walper (1977)
8. BERG - HUGHES
C E N T E R
• Tobosa Basin features
persist through the
Pennsylvanian, as the
location of carbonate
reefs and platforms are
predetermined by
inherited structural
features.
• By early Permian,
compression will trend
uplifts along rift features.
• Uplifts may be related to
advancement of the
OMTB, but because
faulting accommodates
along preexisting planes
of weakness, the
geometries are not
aligned with what we
would expect.
Late Penn/ Early PermLate Miss/ Early Penn
Modified from Wright (2011)
9. BERG - HUGHES
C E N T E R
ReferenceTectonic PhasePeriod
Modified from Romans (2003)
E/W Compression during OMTB advancement
10. BERG - HUGHES
C E N T E R
C C’
• The Val Verde Basin, southeast of the CBP
and in the immediate foredeep of the
OMTB can be accurately modeled with
constant flexural parameters.
• Applying similar constraints west of the
CBP in the DB yields different results
Yang & Dorobeck (1995)
11. BERG - HUGHES
C E N T E R
Yang & Dorobeck (1995)
B B’
• Synorogenic strata do not thicken drastically towards the OMTB,
suggesting minimal flexural influence immediately west of the
CBP.
• Subsidence in the DB a composite of flexure from OMTB and
CBP.
• Yang & Dorobeck suggest the forebulge produced from OMTB
may have been removed by loading from CBP during E/W
compression
12. BERG - HUGHES
C E N T E R
Yang & Dorobeck (1995)
• Flexural profiles accounting only
for CBP loads do not predict
observed thickness.
• Either too narrow or too shallow
• Varying flexural rigidity (D) can
produce better matching
profiles, suggesting crustal
homogeneity – especially in the
SW corner of the DB.
13. BERG - HUGHES
C E N T E R
Gravity anomalies within the DB and CBP
basement, accounting for removal of sediment
overlying the basal Ellensburger formation
Adams & Keller (1996)
• Gravity Anomalies over the DB and CBP further
suggest crustal heterogeneity, as modeled by
igneous bodies underlying basin features.
• Consistent with dates of rifting, and wells
penetrating basement
14. BERG - HUGHES
C E N T E R
Uplift
Depression
Fold-Thrust Belt
Modified from Anthony (2015)
Contact between DB and
CBP – West Platform Fault
15. BERG - HUGHES
C E N T E R
• Diversity of features:
thrusting, folding,
overturned beds,
flower structures.
Shumaker (1992)
16. BERG - HUGHES
C E N T E R
• Yang & Dorobeck (1995) interpret a clockwise rotation of CBP
blocks with emphasis on right lateral west platform faulting
• Shumaker (1992) interprets counter-clockwise rotation of CBP
blocks with emphasis on left lateral cross-platform blocks
• Hoak et al., (1998) synthesizes the two interpretations side-by-side
17. BERG - HUGHES
C E N T E R
Fault map of basal Ellensburger Fm.
With emphasis on CBP-bounding faults
•Emphasis on NNW
trending right-lateral
strike-slip faults,
clockwise block
rotation.
• Requires large
amounts of right-
lateral
displacement on
West Platform
Fault, up to 10km
(Hills, 1970)
•Transpression
causes interior block
rotation of CBP,
producing uneven
E/W shortening
along West Platform
Fault in en echelon
thrust pattern.
Yang & Dorobeck (1995),
Tai & Dorobeck (2000)
18. BERG - HUGHES
C E N T E R
• Shumaker’s model involves similarly
divided CBP blocks, which rotate along a
vertical axis.
• Does not observe large amounts of right-
lateral faulting along West Platform Fault
• Emphasizes E/W trending left-lateral
wrench faulting, suggesting regional
compression.
• E/W translation accounts for differences in
observed deformation.
• Model is confusing, because westward
translation of blocks would cause counter-
clockwise rotation
19. BERG - HUGHES
C E N T E R
• Hoak et. Al., (1998) agrees with Yang &
Dorobeck’s model, stating there are several
right-lateral offset features within the DB.
• Yang & Dorobeck model is more internally
consistent, agrees with surrounding fault
geometries, and incorporates a wider study
area.
Walper (1977)
Yang & Dorobeck (1995)
20. BERG - HUGHES
C E N T E R
Conclusions
Basin Layout
A complex interplay of structural elements giving it the geometries we
observe.
Related to Ancestral Rocky Mountain uplifts, but the geometries do not align
with what we would expect for Marathon Orogeny
Inherited structures
Permian Basin has a history of rifting which influences later movements
Arrangement and trend of features might not align with ‘ideal’ structural
geometries for later events. Tectonic movements are reactivated on
preexisting planes of weakness
Flexural Profile
Superposition of two foreland basin profiles.
Possibility of heterogeneity in the flexural rigidity.
Two Interpretations
Development of structure accounting for observed features.
Comparing consistency of interpretations
21. BERG - HUGHES
C E N T E R
Adams, D. & Keller, G. (1996). Precambrian basement geology of the Permian Basin region of West Texas and eastern New Mexico; a geophysical
perspective. AAPG Bulletin, 80(3), 410-431. Retrieved from http://aapgbull.geoscienceworld.org/content/80/3/410
Anthony, J. (2015). PROVENANCE OF THE MIDDLE PERMIAN, DELAWARE MOUNTAIN GROUP: DELAWARE BASIN, SOUTHEAST NEW MEXICO
AND WEST TEXAS. Repository.tcu.edu. https://repository.tcu.edu/handle/116099117/8303
Galley, J. E., (1958), Oil and geology in the Permian Basin of Texas and New Mexico, in Weeks, L. G., ed., Habitat of oil: Tulsa, Oklahoma, American
Association of Petroleum Geologists, p. 395–446
Hills, J. (1970). Late Paleozoic Structural Directions in Southern Permian Basin, West Texas and Southeastern New Mexico. AAPG Bulletin, 54(10), 1809-
1827. Retrieved from http://archives.datapages.com/data/bulletns/1968-70/data/pg/0054/0010/1800/1809.htm?doi=10.1306%2F5D25CC3B-16C1-11D7-
8645000102C1865D
Hills, J. (1984). Sedimentation, Tectonism, and Hydrocarbon Generation in Delaware Basin, West Texas and Southeastern New Mexico. AAPG
Bulletin, 68(3), 250-267. Retrieved from http://archives.datapages.com/data/bulletns/1984-85/data/pg/0068/0003/0250/0250.htm
Hoak, T.; Sundberg, K. & Ortoleva, P. (1998) Overview of the structural geology and tectonics of the Central Basin Platform, Delaware Basin, and Midland
Basin, West Texas and New Mexico. Germantown, Maryland. UNT Digital Library.http://digital.library.unt.edu/ark:/67531/metadc678963/.
Romans, B.W., (2003) Sedimentation Patterns of a Permian Basinal Cycle, Upper Cutoff, Brushy Canyon, and Lower Cherry Canyon Formations, Western
Delaware Basin, West Texas and Southeastern New Mexico, U.S.A. [Unpublished Master’s Thesis]: Colorado School of Mines, 175 p.
http://dx.doi.org/10.6084/m9.figshare.766363
Shumaker, R. (1992). Paleozoic structure of the Central Basin uplift and the adjacent Delaware Basin, West Texas. AAPG Bulletin, 76(11), 1804-1824.
Retrieved from http://aapgbull.geoscienceworld.org/content/76/11/1804
Walper, J. L., (1977), Paleozoic tectonics of the southern margin of North America: Gulf Coast Association of Geological Societies Transactions, v. 27, p.
230–239.
Whitmeyer, S. J., & Karlstrom, K. E. (2007). Tectonic model for the Proterozoic growth of North America. Geosphere, 3(4), 220-259.
doi:10.1130/ges00055.1
Wright, W. (2011). Pennsylvanian paleodepositional evolution of the greater Permian Basin, Texas and New Mexico: Depositional systems and
hydrocarbon reservoir analysis. AAPG Bulletin, 95(9), 1525-1555. doi:10.1306/01031110127
Yang, K. & Dorobek, S. (1995) The Permian Basin of West Texas and New Mexico: tectonic history of a “composite” foreland basin and its effects on
stratigraphic development, in Dorobek, S. L., and Ross, G. M., eds., Stratigraphic evolution of foreland basins: SEPM (Society for Sedimentary Geology), v.
52, p. 149–174.
Yang, K. & Dorobek, S. (1995). The Permian Basin of West Texas and New Mexico: Flexural Modeling and Evidence for Lithospheric Heterogeneity Across
the Marathon Foreland. Special Publications Of SEPM. Retrieved from
http://archives.datapages.com/data/sepm_sp/SP52/The_Permian_Basin_of_West_Texas.htm
My name is Telly Manos and this is my Presentation on “Structural Relationships of the Delaware Basin and Central Basin Platform”
To give an overview of what I’ll be covering:
-First I’ll give a general overview of the Basin Layout to orient you to the structural geometries.
-In doing so, it will become apparent that the structural geometries don’t necessarily align with dominant tectonic patterns of the time.
-Next I want to talk about inherited structures, and how they’re relevant to the basin development.
-I want to talk about the flexural profile for the Delaware Basin, and how we can think of it as two foreland basin profiles superimposed atop each other.
-Finally, I want to talk about possible interpretations for tectonic development of the basin,
-specifically relating to the margin between the Delaware basin and the CBP, and how different interpretations may not be entirely consistent.
-So this is our map view layout of the Permian Basin in west Texas
-The blue areas represent structurally high areas, the white represents depressions
-The orange along the bottom represents the trace of the Ouichita Marathon thrust belt, which defines the southern extent of the Permian basin.
-The Permian as a whole represents the foreland basin system ahead of the OMTB.
-The Greater Permian encompasses the DB, CBP, MB, and Val Verde Basin.
-They’re all structurally separated internally by fault Bounded uplifts, and along the margin shelves by stratigraphic onlap.
-The West Platform Fault zone encompasses the margin between the Delaware basin and the CBP.
-The CBP is a basement uplift formed from E/W compression, similar to other Ancestral Rocky Mountain uplifts occurring during the Pennsylvanian
-A question I’m not going to address in this presentation is “how did the ARM form” (because that’s a can of worms I’m not going to open)
-Instead we can play with the assumption that E/W compression responsible for ARM uplifts is a result of foreland deformation ahead of the OMTB – leave it at that
-in doing so though, we see that the uplifts are almost normal to the advancing thrust sheet, which really raises more questions than it answers.
-Here’s a cross section going west to east across the Delaware.
-this is typically what get’s modeled in the cross sections, stratigraphic terminations on the west margin
-deepening towards the east, reaching the deepest portions directly adjacent to the CBP uplifts
-Then we have this steeply dipping fault surface bordering the CBP.
-this is the West platform fault zone that I mentioned earlier. It’s modeled as everything from thrusting and overturned beds, extension, strike slip, you name it.
-Not a lot of people agree with a consistent notion of what’s going on here
-We have to come up with a creative model that can explain all the structures we see here.
-on a final note, most of the carbonate reefs are located directly above the CBP, suggesting there was a significant topographic influence at the time of their formation.
-Next I want to talk about the basin history, and how it relates to the later features.
-It’s important to keep the history in mind, because most of the later Permian features are inherited from prior events.
-Our earliest event is going to be midcontinent rifting taking place during the Grenville represented by the purple worm.
-We can see that the trace of this rifting continues up from the great lakes, and is interpreted as continuing all the way down to west texas
-This rifting event is what’s going to define those steeply dipping fault detachment surfaces and establish preexisting planes of weakness.
-It’s also going to lay our basement igneous rocks including a layered mafic intrusion under the CBP, and several felsic granite bodies under the adjacent basins
-Secondary, we’re going to have a late proterozoic ‘sag basin’ superimposed on top of earlier rifting, causing additional subsidence along what was at this time a passive continental margin.
-we don’t interpret major structural subsidence occurring during this event, even though there might be movement on the Grenville faults,
-all of our igneous basement is dates past 1 Ga, so no intrusions are relevant to rifting during this time
-We can determine the location and magnitude of this subsidence though by looking at unit thicknesses of the Tobosa Basin which existed prior to the DB.
-Which is a series of passive margin carbonates accumulating during this subsidence
- The Tobosa basin set the basal units for the Later Paleozoic units to be laid overtop
-Of particular importance though, is the depocenter of then Tobosa coincides with the Depocenter of the later Delaware.
-This suggests that the topographic controls of both basins share a similar feature – structural inheritance.
-We see a similarity with other extensional basins formed at the same time, specifically the southern Oklahoma Aulacogen (or the Wichita Aulacogen).
-both involve ancestral rocky mountain uplifts with adjacent extensional basins that were later inverted.
-All these extensions are associated with the breakup of rhodinia, starting in the East with Mt. Rodgers, and progressing westward to the Tobosa. Indicating a timeline of rifting.
-The Wichita and reelfoot aulacogens are more failed rift systems (think triangle geometries), while the Delaware is a passive-margin sag basin.
-To reiterate: When we talk about the ‘Delaware Aulacogen’ most of those structural features were already pre-established by the rifting occurring during the Grenville.
-Subsidence took place overtop of these features.
-These structural features are going to persist through to the Permian, as the locations of our carbonate margins are predetermined by the topographic highs in the Tobosa Basin
-Later in the late Pennsylvanian once we get E/W compression those uplift trends are going to align themselves with the preexisting planes of weakness formed during Grenville Rifting.
-Now I want to point out the direction of movement along the OMTB: moving north/northwest.
-Because the fault surfaces bordering the CBP are oblique to the direction of movement, we’re going to get transpressional movement along these preexisting faults instead of fracturing new surfaces parallel to regional compression.
-So just to recap the tectonic timeline of our structural features:
-Grenville rifting in the Proterozoic
-Passive Margin sagging during the Eocambrian
-Tectonic nothingness through the Mississippian
-Finally the Marathon Ouachita Orogeny during the Pennsylvanian
-Now I want to talk about the flexural profile of the Delaware Basin.
-When we look east of the central basin platform and draw a cross section, we see all the classical elements of a foreland basin system.
-We have our foredeep in the Val Verde, we have a nice forebulge in the Ozona Arch, and we have our backarch in the midland basin.
-This profile can be readily matched using a flexural rigidity of 4X10^22 N M
-However, when we jump across the Central Basin platform into the Delaware things change.
-Our Delaware basin doesn’t follow the same constraints on the west side of the CBP that the rest of the Permian did on the east side.
-The vertical exaggeration can be a bit misleading, but we can see we’re missing a forbulge, and Pennsylvanian thickness doesn’t get much thicker towards the thrust front.
-Once way we can account for this change, is that there is significantly more E/W directed thrusting in the DB than there was in the MB
-This way, we can think of the DB being two foreland basin profiles superimposed on each other, one directed N/S from the OMTB and one directed E/W from the CBP.
-This causes certain features such as the forebulge or deflection curve to be overwritten, basically producing one synchronous subsidence depression.
-However, things only get more complicated from here.
-Yang and Dorobeck produced a series of flexural profiles incorporating topographic loads just from the CBP.
-They determined that by varying the flexural rigidity and load, they couldn’t produce a profile matching observed thicknesses, suggesting the CBP wasn’t acting alone as a subsidence mechanism.
-Their profile was either too narrow or too shallow.
-One thing they did note though is that by varying the flexural rigidity across the basin, they could produce more consistent matches with observed thicknesses.
-This suggests there’s heterogeneity in crustal composition across the basin leading to varied flexural parameters.
-Adams and Keller in a 1996 publication further reinforced the idea of crustal heterogeneity when they compiled gravity anomalies over the Permian Basin.
-when removing the overlying sediment, we see the gravity anomalies follow the trace of the CBP and DB, suggesting there's significant variability in the crustal makeup.
-Using datapoints obtained from wells that had penetrated basement, they implied a series of igneous intrusions that could produce the densities leading to the gravity profile they measured.
-This reinforced the idea that the Grenville were the dominant structural contributors
-Moving forward I’d like to talk about the contact between the DB and CBP.
-This West Platform fault is anything but uniform, and produces several interesting structures that define a lot of the oil plays in the basin.
-Within this fault zone, we see thrusting, overturned beds, folding, a few areas of extension, and both right and left-lateral faulting normal to each other.
-most importantly: Flower structures.
-Ideally, we have to come up with a model that can account for all these features: so basically every movement ever.
-Two schools of thought exist, one championed by Yang and Dorobeck in their 1995 publication series, the other championed by Robert Shumaker in a 1992 publication.
-conveniently for me, shortly after there was also a great summary by Hoak et al. comparing the two interpretations and highlighting their main differences.
-The best way to compare the two is that both models break the CBP into smaller fault-bounded blocks that are rotating along a vertical axis
-Yang and Dorobeck interpret clockwise rotation, with dominant N transverse movement
-Shumaker interprets coutner-clockwise rotation with dominant W transverse movement
-So both models define their blocks based on fault maps of the Ellensburger formation, which is the basal Cambrian-Ordovician carbonates formed in the Tobosa Basin.
-Any fault surfaces affecting Pennsylvanian and Permian strata have to go through this formation
-They divided the CBP into two simple blocks, which are fault bonded and internally consistent
-This model focuses on N-directed right-lateral wrench faulting along the trace of the west platform fault, estimating up to 10km of displacement.
- This rotation causes clockwise rotation of these blocks.
-I apologize for the potato quality of the figure on the lower left, but through rotation we can account for:
(1) thrusting in the SW corners
(2) extension along the NW corners
(3) right lateral faulting joining the two
(4) left lateral faulting separating the two blocks
(5) increased displacement of cutoff points in the SW corners of each block
-Shumaker’s model differs in that he places greater emphasis on E/W directed wrench faults with left-lateral movement.
-His observations don’t include large amounts of right lateral faulting on the west platform fault,
-He emphasizes E/W compression translating to differential amounts of compression along the CBP margin producing the observed displacements in cutoff points.
-His model is confusing because the geometries he describes should produce counter-clockwise rotation, which is not what we observe (or what he maps)
-This raises a larger ‘chicken or the egg’ question: Does lateral faulting induce rotation of these blocks, or does the block rotation induce lateral movement along the block margins?
-Hoak et al. in his synopsis is more inclined to agree with Yang and Dorobeck.
(1) They’re Aggies, so automatically their interpretation is better.
(2) There is significant evidence of right-lateral faulting on the west platform fault
(3) Their argument is more internally consistent, and incorporates more observed elements than Shumaker’s model
(4) several features are right-lateral displaced between the east and west side of the CBP, including the Grisham anticline and the Grisham fault.
-Interestingly enough, Walper goes so far as to call the Grisham anticline the ‘forebulge’ of the OMTB, and attributes it’s displacement due to the orocline in the OMTB.
-This curve here extending further into the foreland than the right limb.
So in conclusion:
-I covered the general layout of the Delaware basin
-I talked about the inherited structures and how they relate to the later geometries
-I discussed attempts at modeling the flexural profile, and the implications that had for crustal heterogeneity
-Finally I talked about two schools of thought concerning the development of the CBP, and how one was obviously better than the other.
Here’s some references I used. Specifically, the two Yang and Dorobeck papers which basically tell you everything you need to know
Thanks you!
We will now have a few minutes for questions.