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Results
Multidisciplinary approach in determining the best zone to land a Haynesville horizontal well
Liu, Shujie (BP) | Zett, Adrian (BP) | Spain, David (BP) | Rabinovich, Michael (BP) | Gillham, Travis (BP) | Gangopadhyay, Abhijit (BP) | Lucas, Jennifer (BP) | Zhou, Qiang | Gysen, Alain
Abstract The Upper Jurassic Haynesville Shale Formation in the East Texas Basin, North America, is a black, organic-rich, calcareous mudstone that lies below the Bossier Shale and above the Cotton Valley Limestone. The reservoir quality was controlled by primary depositional process and secondary diagenesis. The best lithology type in terms of drilling, completion, and production is the organic-rich, silty calcareous mudstone with low clay content. The studied well traversed the entire Haynesville Formation with the objective to assess the production potential of this formation. We acquired open-hole, triple-combo logging while drilling (LWD) logs, two types of production logs, and regional microseismic data. Postdrill log modeling confirmed that the horizontal well stayed on the planned trajectory, based on the log correlation between the horizontal and offset wells. Log modeling demonstrated that the LWD resistivity logs in horizontal wells are subject to resistivity anisotropy and polarization horn effects. We integrated the production log results with the open-hole, log formation evaluation and mineralogy-based brittleness index, to understand the static reservoir properties and dynamic inflow performance. The open-hole and cased-hole logs consistently showed that the “rabbit ears” interval at the base of the Upper Haynesville and the top interval of the Upper Haynesville were excellent lateral well-landing zones for best production. We combined microseismic data with production log data and found that the effective stimulated rock volume by hydraulic fracturing was mostly concentrated in the top interval of the Upper Haynesville and the “rabbit ears” interval at the base of the Upper Haynesville. The study demonstrated that a multidisciplinary approach was necessary in determining the best zone to land Haynesville horizontal wells.
- North America > United States > Texas (1.00)
- North America > United States > Louisiana (1.00)
- Geophysics > Seismic Surveying > Passive Seismic Surveying > Microseismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- North America > United States > Texas > Haynesville Shale Formation (0.99)
- North America > United States > Louisiana > Haynesville Shale Formation (0.99)
- North America > United States > Louisiana > Haynesville Formation (0.99)
- (7 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- (2 more...)
Understanding Unconventionals by Multidisciplinary Integration - A Microseismic Based Tale of the Haynesville Shale
Gangopadhyay, Abhijit (BP America) | Malayalam, Atif (BP America) | Lucas, Jennifer (BP America) | Gillham, Travis (BP America) | Liu, Shujie (BP America) | Faz, Ignacio (BP America) | Wirnkar, Fabian (BP America)
Abstract Microseismic data acquired using a near-surface array in four horizontal wells in the Haynesville shale in Shelby and San Augustine counties, Texas, were analyzed and integrated with geoscience, petrophysics, completions, and flow-back performance data. Horizontal sections of the wells are ~5,000 feet long, and stimulated with twelve stages. Analyses of microseismic events from the first two wells to understand fracture containment, led to drilling the fourth as a transverse across the target zone. A production log was also run in the same well to identify zones in the Haynesville that produced the highest rate of gas. Fewer microseismic events were recorded during stimulations of the northward wells, and resulting fractures were more elongated than the southward wells. Fracture half-lengths based on all located microseismic events from the four wells range between ~400 feet and ~700 feet. The derived fracture orientations are consistent with the regional SHmax and confirm our choice of well azimuths. Some prominent fractures align with those inferred from 3-D seismic based coherency attribute, indicating that pre-existing fractures were activated. Correlations of microseismic event locations with gamma ray logs along the laterals revealed that fractures initiated better when the log values are <110 API, an observation consistent with Lithology-based brittleness index. The completions strategy included pumping resin coated sand in one well, combining that with white sand in others, and stimulating the shortest lateral with the same proppant volume and stages as others. Flow-back performance of the shortest lateral was strong enough to suggest the potential for reserve improvement by shortening stage length. The interpreted production log shows that stages near the heel are most productive compared to the first three stages near the toe, leading to an estimate of the effective stimulated rock volume. Summarily, the study provides multidisciplinary insights into future horizontal designs in the area.
- Geology > Petroleum Play Type > Unconventional Play > Shale Play > Shale Gas Play (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.89)
- North America > United States > Texas > Haynesville Shale Formation (0.99)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- North America > United States > Louisiana > Haynesville Shale Formation (0.99)
- (7 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Analysis and Integration of Near-Surface Array Microseismic Data from the Haynesville Shale
Gangopadhyay, Abhijit (BP America) | Malayalam, Atif (BP America) | Lucas, Jennifer (BP America) | Gillham, Travis (BP America) | Liu, Shujie (BP America) | Faz, Ignacio (BP America) | Wirnkar, Fabian (BP America)
Abstract A case study is presented which combines and integrates analyses of microseismic data, production logs, hydraulic fracture treatments, and flow-back performance from four horizontal wells in the Haynesville shale, east Texas. The laterals of the wells are approximately 5,000 ft long, oriented N-S, and each stimulated with twelve stages. Three of the laterals were geo-steered within a 18 ft target window, whereas one was drilled transverse across a 131 ft window. The production logs were run in the transverse lateral to identify zones in the Haynesville that produced the most gas. The microseismic data were obtained using a dense near-surface permanent array spanning ~30 square miles. Based on 1,229 microseismic events, inferred fracture half-lengths range between ~423 ft and ~675 ft. About half the lengths of most of these fractures are contained within the target reservoir interval. Inferred fracture orientations range between ~13° and ~164°, consistent with regional SHmax, thereby supporting our choice of well azimuths. Some of these fractures align with those observed on 3-D seismic based coherency, implying that pre-existing fractures have been activated. Stimulations of northward wells caused less microseismic events, but generated more elongated fractures than southward wells. Additionally, the southward wells with higher microseismic activity implying greater initiation and stimulation of fractures, correlate well with gamma ray log values <~110 gAPI, compared to their northward counterparts, where gamma ray log values in their laterals are predominatly >~110 gAPI, indicating a possible diagnostic of fracture capability, consistent with lithology-based brittleness index. The completions strategy involved pumping resin coated sand in one well, combining that with white sand in others, and stimulating the shortest lateral with the same proppant volume and stages as others. Interpreted production log from the transverse lateral shows that stages near the heel are most productive compared to the first three stages near the toe, leading to an estimate of the effective stimulated rock volume. Overall the study provides multidisciplinary insights into design of future horizontals in the area
- Geology > Petroleum Play Type > Unconventional Play > Shale Play > Shale Gas Play (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.89)
- North America > United States > Texas > Haynesville Shale Formation (0.99)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- North America > United States > Louisiana > Haynesville Shale Formation (0.99)
- (7 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Microseismic Using a Near-Surface Array – A Case Study in the Haynesville Shale, East Texas
Gangopadhyay, Abhijit (BP America) | Johnston, Rodney (BP America) | Lucas, Jennifer (BP America) | Ramirez, Jaime (BP America) | Gillham, Travis (BP America) | Peña, Victor (BP America) | Wirnkar, Fabian (BP America)
Summary We report on the analyses of microseismic data collected using a near-surface array during fracture stimulation of two horizontal wells in the Haynesville shale, east Texas. Processing of the data reveal relatively high noise levels that present significant challenges in unmasking the underlying microseismic event signals. Orientations of fractures resulting from the well stimulations as observed from analyses of all located events range between 25° and 130°, and thereby suggest that the well azimuths are geomechanically consistent with the regional stress field. The number and size of microseismic events appear to be influenced by increase in bottom hole injection pressure caused by increase in pumping pressure and/or proppant concentration. Average fracture length and height obtained from the analyzed data considering either side of the well bore together are ~1200 feet and ~440 feet respectively. The results from the project confirm some aspects of well design and completions strategies, while providing important insights into improving future plans.
- Geology > Petroleum Play Type > Unconventional Play > Shale Play > Shale Gas Play (0.74)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.64)
- North America > United States > Texas > Haynesville Shale Formation (0.99)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- North America > United States > Louisiana > Haynesville Shale Formation (0.99)
- North America > United States > Arkansas > Haynesville Shale Formation (0.99)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)