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Hydraulic Fracturing Test Site II (HFTS2) – Delaware Basin
Project Number
DE-FE0031577
Last Reviewed Dated
Goal

The objective of this project is to conduct a field-based hydraulic fracturing research program in the Delaware Basin portion of the Permian Basin in West Texas. This project will advance hydraulic fracturing technology, optimize well spacing, and mitigate environmental impacts of shale development operations. The research will advance our understanding of the hydraulic fracturing process in shale reservoirs, thus enabling the design and execution of effective fracture stages that significantly contribute to production. Improved design and execution of fracture stages will also reduce the number of future infill wells drilled and reduce water volume and energy input. This project will build upon the learnings from the HFTS1 project and advance the understanding of hydraulic fracturing. 

Performer(s)

Gas Technology Institute, Des Plaines, IL 60018

Background

The Permian Basin is one of the most prolific oil and natural gas geologic basins in the U.S. It is central to America’s energy resurgence, enabled by development of the shale resources within U.S. geologic basins. The Permian-Delaware Basin produces more than 50,000 barrels of oil per day and is an area of active development. The Permian Basin is approximately 250 miles wide and 300 miles long across West Texas and southeastern New Mexico. It encompasses several sub-basins, including the Delaware Basin and the Midland Basin, where the HFTS1 test site was located. Given the complexity of shale formations, significant geotechnical differences occur within the respective basins over very short distances. The Delaware Basin is a deeper basin than the Midland with vertical well depths up to 10,000 feet. The Delaware Basin is also a geo-pressured basin, adding to the difference between the two basins. From a geologic and geotechnical perspective, industry considers them separate and distinct basins.

Despite the long history of hydraulic fracturing, the optimal number of fracturing stages during multi-stage fracture stimulation in horizontal wells is not known. In addition to the increased expense of multistage fracturing in horizontal wells, increasing the number of fracturing stages does not always correlate with an increase in production. The problem is the application of a uniform fracture stimulation design to all stages with no consideration for geological variations along the wellbore. The result is an inefficient use and a costly waste of energy and water. 

Optimization of the fracturing process requires an understanding of the cause-and-effect relationship between fracturing parameters and local geological properties at a given location along the wellbore. Realizing that the generalized rock mechanics theories and hypotheses are not truly applicable to fractured and laminated shales, quantifiable impacts of a shale’s geomechanical and depositional features are a prerequisite for design and implementation of optimized hydraulic fractures. The overarching goal of this project is to understand and define the relationships of shale geology and fracture dynamics using detailed field data that includes coring of the fracture domain. Analyses of the data will aid in updating fracture design models and improve the effectiveness of individual hydraulic fracture stages.

Impact

The HFTS2 field test site provides the opportunity to address the “billion-dollar problem,” or the optimal development of a “stacked pay” resource which requires simultaneous drilling and completion of tens-of-thousands of wells across multiple geologic horizons. Drilling too many wells results in a waste of resources such as water, steel casings, and other infrastructure while adding to emissions issues and land footprint. Drilling too few wells, from the perspective of well spacing, leaves valuable resources in the ground. Research results from this project are expected to have positive impact on economic, environmental, and resource recovery factors.

Simultaneous drilling and completion of wells in multiple geologic formations can reduce the overall cost of oil and gas production on a per-well basis, thus providing more drilling locations in the future, even at lower oil/gas prices. Continued long-term production adds jobs and increases economic output of the producing region and the U.S. economy.

The greatest beneficial impact to be derived from the proposed research will be achieved through determination of optimum well spacing and hydraulic fracture design. If the resulting optimization leads to a resource recovery increase of 1%, an additional 1.6 billion barrels of oil could be recovered from the Permian Basin. This optimization further leads to elimination of many wells currently drilled at non-optimum well spacing. 

Accomplishments (most recent listed first)
  • Completed Project Management Plan (PMP)
  • Completed Data Management Plan (DMP)
  • Completed the Environmental Questionnaire and received National Environmental Policy Act (NEPA) approvals
  • Held multiple workshops with experts from the participating companies and DOE/NETL in order to develop a draft testing and field data acquisition plan
  • Signed agreement with Anadarko Petroleum (now Occidental) to host the field test site
  • Signed participation agreements with numerous producing companies to join the HFTS2 project and provide cash and/or in-kind co-funding (currently 17 industry participants)
  • Acquired background data from Anadarko Petroleum (now Occidental) for ~24 wells in the vicinity of the test site
  • Implemented a data sharing platform and created a framework for data management and data sharing with project members
  • Finished drilling, coring, instrumenting, and casing the vertical pilot well; the vertical pilot well was instrumented with permanent behind casing fiber optic cable along the entire measured depth of the well and discrete pressure gages
    • Completed core analysis on recovered vertical core
  • Drilled remaining horizontal wells and installed permanent fiber optic cable in two wells, along with permanent toe and heel gages
  • Logged three horizontal wells
  • Completed Diagnostic Fracture Injection Tests (DFIT’s) on four horizontal test wells
  • Pumped 262 fracture stages while monitoring with various diagnostics, including Distributed Acoustic Sensor (DAS) and Distributed Temperature Sensing (DTS), microseismic, cross-well DAS strain, high-frequency surface pressure gages, bottomhole gages, and others
  • Added additional industry members to the program
  • Completed proppant analysis (proppant log) from mud returns during drilling of a child test well lateral
  • Installed tubing and bottomhole pressure/temperature gages in all producing wells and placed wells on production
  • Completed two production/pressure interference tests to assess reservoir pressure response and test new Rayleigh Frequency Shift Distributed Strain Sensing Fiber Optic interrogator technology
  • Drilled a slant core well and recovered over 940 feet of whole core through the created fractures and installed 12 discrete pressure/temperature gages in the well
  • Completed fracture description on over 1200 fractures contained in the core
  • Completed proppant analysis on more than 300 core sludge samples
  • Completed time-lapsed oil geochemistry analysis on 4 wells with 5 temporal sampling points 
Current Status

 Bottomhole pressure and temperature data from all wells are currently being collected, including the producing test wells and the two monitor wells, and plan to collect this data to project completion.  In addition to collecting the aforementioned data, an integrated fracture simulation study was commenced in which one or more simulation models will be built, and history matched using the unique HFTS2 dataset, and then will run design sensitivities to help optimize frac design parameters such as cluster spacing and well spacing.  This 6-month effort is scheduled to be completed in Q4 2021.

In support of technology transfer, the HFTS-2 members have agreed to publish 16 papers with HFTS-2 results and learnings and present the papers at the 2021 Unconventional Resources technology Conference in July 2021, in a HFTS-2 Special Session.
 

Project Start
Project End
DOE Contribution

$7,799,052

Performer Contribution

$12,590,025

Contact Information

NETL – Gary Covatch (gary.covatch@netl.doe.gov or 304-285-4589)
GTI – Jordan Ciezobka (Jordan.ciezobka@gastechnology.org or 847-768-0924)