Multi-Component Seismic Analysis and Calibration to Improve Recovery from Algal Mounds:  Application...
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Multi-Component Seismic Analysis and Calibration to Improve Recovery from Algal Mounds: Applications to the Roadrunner/Towaoc Area of the Paradox Basin, Ute Mountain Ute Reservation, Colorado. Goals:

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Goals

Multi-Component Seismic Analysis and Calibration to Improve Recovery from Algal Mounds: Applications to the Roadrunner/Towaoc Area of the Paradox Basin, Ute Mountain Ute Reservation, Colorado


Goals

  • Goals:

  • Develop an approach to identify algal mounds and their productive characteristics with greater accuracy

  • Benefits:

  • More cost effective production from existing algal mound fields

  • Better success for discovering new algal mound fields


Goals

PARADOX BASIN UPPER ISMAY ALGAL MOUND PLAY

The Paradox Basin extends from Utah into Colorado. One exploration target with significant discoveries still possible is the Ismay Algal Mound Play.

The potential exists because these mounds may have little structural expression, and complex reservoir heterogeneity making accurate siting of wells critical to success.


Goals

Algal Mounds

Algal Mound (Salar d’Uyuni, Bolivia)

Muleshoe bioherm, a 60 m high reef mound of Late Mississippian age exposed along the western escarpment of the Scaremento Mountains, New Mexico.


Goals

Algal Mounds can have a substantial amount of internal reservoir heterogeneity


Goals

Game Sixteen: December 23 – Pittsburgh at Tampa Bay.

“After analysis on Warren Sapp playing offense for the Buccs, I liken it to a 3-D seismic data with several types of seismic attributes revealing geologic factors that control the location of productive algal mound reservoirs in the Paradox Basin.” (anonymous posting on sports website http://www.baseballology.com/warrzone/article.php3?ArticleID=788)


Goals

PROJECT TEAM MEMBERS

  • Ute Mountain Ute Tribe

  • Red Willow Production Company

  • Legacy Energy

  • Colorado School of Mines

  • WesternGeco

  • Axis Geophysical

  • Eby Petrographic Services

  • Schlumberger Oilfield Services

  • Golder Associates

  • U. S. Dept. of Energy


Goals

Technical Oversight & Planning

Legacy Energy (Claudia Rebne)

Technical Manager - Seismic

Red Willow (Steve Dobbs)

Technical Manager - Geology

Colorado School of Mines (Tom Davis) – Seismic Acquisition & Interpretation Review

Solid State – (Trent Middleton) 3D Seismic Acquisition

Schlumberger (Richard Pearcy ) – 3C VSP Acquisition

Technical Contractors

WesternGeco (Rich Van Doak) – “Conventional” 3D Seismic Processing

Axis Geophysics (Bob Parney) – AVO 3D Seismic Processing

Eby Petrograhpic (Dave Eby) – Core Studies

PROJECT MANAGEMENT ORGANIZATION & RESPONSIBILITIES

U. S. Dept. of Energy (Virginia Weyland) Contract Manager

Golder Associates Inc. (Paul La Pointe) Project Management

Ute Mountain Ute Tribe - Resource and Land Owners


Goals

ALGAL MOUND EXPLORATION & RESERVOIR DEVELOPMENT CHALLENGES

Upper and Lower Ismay carbonates produce oil and gas from porous algal mounds at drill depths of about 6000’. Anhydrites provide a top and lateral seal. The mounds generally trend northwest to southeast and are typically 1 to 2 miles long and ¼ to ½ mile wide. Typical field sizes are 1 to 5 MMBOE with average per well reserves of about 300,000 BOE. Some wells have produced over 1 million BOE.

Upper Ismay carbonate mounds are generally 50 to 100’ thick, while Lower Ismay mounds are 40-70’ thick. Mounds are surrounded and overlain by Upper Ismay massive anhydrite that thins abruptly over the tops of the mounds. Lateral stratigraphic changes from porous algal mound facies to off-mound anhydrite facies are abrupt. The key factor associated with the exploration of Ismay algal mounds is predicting these stratigraphic changes. Secondary exploration risk factors include predicting porosity, permeability and fluid content of mounds.

Development of a detailed lithologic model over a known reservoir is a critical technical issue in calibrating the seismic data for reservoir development and future exploration. A detail core study of the Road Runner and Towaoc fields is included in the proposed work to resolve this issue.


Goals

Conventional 3D Seismic was first used in the mid-1990’s.

This improved drilling success (~50% success) as it did a much better job in delineating lateral stratigraphic changes from off-mound anhydrite to porous carbonate mound.

OVERVIEW OF PREVIOUS USE OF SEISMIC IN ALGAL MOUND EXPLORATION IN THE PARADOX BASIN

Conventional 2D Seismic was used in Early 1980’s for Exploration.

This improved drilling success, but many dry holes were still drilled because of Fresnel zone and out-of-plane migration problems


Goals

AN EXAMPLE: THE KIVA FIELD

The 1984 discovery of Kiva field was the result of a geologic model that was confirmed by conventional 2D seismic data. The seismic data was carefully processed and took into consideration the cyclic nature of the geology in the Paradox Formation.

After the confirmation well flowed 1,050 BOPD + 750 Mcfgpd from the Upper Ismay, Meridian Oil and BWAB proceeded in January 1985 to acquire a 3D seismic survey over the possible extent of the new field. The results of that survey show that the 3D images the porous part of the algal mound and demonstrates mound morphology. The survey also demonstrates that the conventional 2D strike line images the crest of the mound from out of the plane of the section (sideswipe), and the 3D migration of the data volume is able to place the image of the mound into its proper position.


Goals

ANOTHER EXAMPLE: THE BLANDING PROSPECT AREA

The porous mounds are encased in thick massive anhydrite which thins or disappears over the tops of the mounds. This lithology change produces seismic amplitude dims and isochron thicks. The 2D seismic data from the 1980s are used to identify prospects, and new 3D seismic surveys provide for accurate imaging of the thickest and most prolific parts of the algal mounds.

The Horse Canyon Federal # I - I 0 well was drilled just south of the Blanding Prospect Area by Miller Energy in 1998. This well location was based on 3D seismic data, and is only 700 feet away from a dry hole drilled in the 1980s based on 2D seismic data. The well IP'd for 960 BOPD and 3 MMCFGPD. This is a good case history illustrating that the older 2D seismic data did reliably detect a mound, but the 3D seismic data was required to image the productive portion of the mound and resulted in a prolific new discovery.


Goals

SUMMARY

2D Seismic good for finding mound complexes, but bad for describing geometry of mound and lateral facies variations

Conventional 3D good for describing external mound geometry, and better at describing facies variations and reservoir quality, but still imperfect for reservoir properties and internal geometry


Goals

WHY 3D MULTI-COMPONENT SEISMIC?

The key to developing a better image of the reservoir’s internal geometry and flow properties is to utilize fluid saturations and azimuthal processing that can directly respond to oriented heterogeneities and changes in fluid saturations.

Thus, acquisition of shear-wave data and advanced azimuthal processing or both shear- and compressional-wave data will potentially provide a much higher resolution of internal mound geometry and, from a reservoir engineering standpoint, a better model of the distribution of reservoir porosity and permeability.


Goals

STRATEGY

  • Acquire 3D Multi-Component data over existing algal mound production as well as off-mound area (Towaoc & Roadrunner Fields)

  • Acquire a Multi-Component VSP (vertical seismic profile) in a well to help calibrate 3D processing and acquisition

  • Process 3D data for P-wave, S-wave, AVO and anisotropic velocity attributes

  • Calibrate processed seismic data against core a facies interpretations

  • Calibrate processed seismic data against reservoir engineering data


Goals

LOCATION OF PROJECT AREA


Goals

Close-up of 6 Square Mile 3D Shoot Area


Goals

Seismic Workscope Activities


Goals

Data

Core and Well Data

 10 cores in either the Upper or Lower Ismay in the immediate area. Including relevant core from the surrounding area a total of 500 feet of core.

34 wells: 3wells with well histories and conventional logs. 19 of the 34 wells are producing wells and have production data

 Detailed tops database and subsurface mapping (Red Willow)

Existing Seismic Data

 600 miles of conventional 2-D data already acquired. 100 miles of which are currently being reprocessed by Red Willow.

Seismic data to be acquired during study

 6 square miles of three-dimensional, three-component data.

 1 full waveform VSP to calibrate to the S-wave seismic data.


Goals

Phase 1: Data gathering and acquisition

Task

Description

Result

Task 1.1: Core and log data gathering

Assemble data base, gather electronic and paper well data, schedule access to cores

Task 1.2: Seismic Acquisition

Acquire three dimensional three-component seismic data

3D3C seismic data field tapes.

Task 1.3: VSP Acquisition

Acquire three component Vertical Seismic Profile

Three component VSP.

Task 1.4: Seismic Processing

Process all seismic data including conventional P-wave, anisotropic P-wave, azimuthal AVO, and S-wave processing

(1)Conventional P-wave data volume.

(2)Anisotropic velocity P-wave data volume.

(3)Azimuthal AVO data volume

(4)S-wave volume


Goals

Phase 2: Data analysis

Task

Description

Result

Task 2.1: Core study

Map on and off reservoir lithology by using cores, thin sections and conventional logs.

Lithologic model and map.

Task 2.2: Conventional Seismic interpretation

Interpret the conventional (Three dimensional P-wave) data volume in order to calibrate seismic data to lithology.

P-wave time thickness and attribute mapping.

Task 2.3: S-wave and attribute seismic interpretation

Interpret the 3 seismic data volumes in order to calibrate seismic data to lithology.

(1) S-wave time thickness and attribute mapping.

(2)Anisotropic velocity map.

(3)Azimuthal AVO mapping.

Task 2.4: Engineering data interpretation

Examine production data and well tests to correlate reservoir performance to lithology.

Production index (PI) map of reservoir and inferred permeability.


Goals

Phase 3: Modeling

Task

Description

Result

Task 3.1: Lithologic/geologic structure modeling

Build model for seismic modeling based on core study (Task 2.1)

3-D computer model of lithology based on core analysis.

Task 3.2: Stress field model

Develop map of 3-D stress field based on velocity anisotropy (Task 2.3)

3-D computer model of stress based on anisotropic velocity analysis.

Task 3.3: Seismic simulation

Determine link between seismic response and both lithology and stress by modeling the seismic response interpreted in Tasks 2.2 and 2.3 and determine if there is a link between the seismic data and the lithology and stress (Tasks 3.1 and 3.2)

3-D computer model of seismic response based on lithology, conventional seismic interpretation, attribute mapping and results of stress field mapping.

Task 3.4: Flow simulation

Demonstrate link between seismic response and reservoir response (i.e. permeability, porosity etc.) by simulating flow through geologic model developed in tasks 3.1, 3.2, and 3.3 and the engineering data interpreted in task 2.3

3-D reservoir simulation incorporating all previous mapping and modeling tasks to show extent to which seismic data can predict internal mound architecture.


Goals

Phase 4: Reporting

Task

Description

Result

Task 4.1 Workshops for tribes

Workshops for tribes and all relevant parties

(1)Initialization workshop

(2)Mid-project progress workshop

(3)Project wrap up workshop

Task 4.2 Website

Website containing project info, technical transfer of findings, status reports and project learnings

Website

Task 4.3 Reporting

Progress and final reports for the DOE and tribes

(1)Three bi-annual reports

(2)One final report

Task 4.4 Briefing for Core

Presentation of status and results for DOE in Tulsa

Presentation for Core as required by solicitation

Task 4.5 Journal articles and public presentations

Publication of one paper in a peer-reviewed journal, and presentation of results and a technical conference

(1)Published technical paper

(2)Conference presentation


Goals

Project Schedule


Goals

Project Status

  • WesternGeco’s decision to leave the seismic acquisition business in North America required finding a new contractor. SolidState will be doing acquisition, but this phase of the project has been delayed about 5 months as a result

  • Permitting in progress for acquisition

  • Seismic processing and acquisition teams are interacting to optimize survey and processing results

  • VSP planning underway


Goals

Near-Term Activities

  • SPRING 2003

  • Permitting of 3D acquisition

  • Acquisition of 3D multicomponent data

  • VSP acquisition

  • SUMMER 2003

  • Processing

  • Preliminary Interpretations

  • Core Study


Goals

Contacts for Key Personnel

AXIS Geophysics

Bob Parney

(303) 831-0544

(303) 318-7798 (fax)

[email protected]

Legacy Energy

Claudia Rebne

(970) 325-0038

(303) 475-5292 cell

(801) 457-7765 (fax)

[email protected]

WesternGeco

Rich Van Dok

(303) 629-9250

[email protected]

CSM Reservoir Characterization Group

Tom Davis

(303) 273-3938

[email protected]

Red Willow Production Company

Steve Dobbs

(970) 563-0140 or (970) 563-0145

(970) 563-3681 (fax)

 (970) 759-1340 (cell)

[email protected]

Eby Petrographic

Dave Eby

(303) 738-9697 or 778-7173

(303) 730-3698 (fax)

[email protected]

Schlumberger

Richard Pearcy

(972) 789-7736

[email protected]

Golder Associates Inc.

Paul La Pointe

(425) 883-0777

(425) 882-5498 (fax)

[email protected]

Solid State

Trent Middleton

(403) 255-9388

(403) 255-4697 (fax)

[email protected]


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