Jurassic Haynesville Research Articles

Origin of bedding-parallel calcite “beef” layers in the Upper Jurassic Haynesville shale, northwestern Louisiana

Origin of bedding-parallel calcite “beef” layers in the Upper Jurassic Haynesville shale, northwestern Louisiana

Velocity modeling of supercritical pore fluids through porous media under reservoir conditions with applications for petroleum secondary migration and carbon sequestration plumes

Computational methods to characterize secondary migration in porous media traditionally rely on fluid transport equations with assumptions of time invariance, such as flow-path modeling of buoyancy vectors, statistical percolation algorithms, capillary pressure curves, or a form of Darcy’s law, which presumes instantaneous fluid transport. However, in petroleum systems modeling, the timeframe of secondary migration from source to reservoir is important to quantify in relation to other geologic factors, such as the timing of petroleum generation, fault movement, and seal formation. In addition, quantifying migration velocities enables an estimation of the distance a plume of geologically sequestered carbon dioxide travels over time, as well as the identification of low-permeability strata appropriate for long-term containment. This study introduces a method to quantify transport velocities of supercritical fluids in low-permeability lithologies for a broad range of rock and fluid properties likely encountered in the sedimentary sequence. A time-dependent form of Darcy’s law for pressure-driven viscous flow through homogeneous isotropic porous media was used to model flow velocities within a carrier bed. Thermodynamic equations of state were used to determine thermophysical properties of supercritical pore fluids under reservoir pressures ranging from 0 MPa to 200 MPa (0–29,000 psi) to constrain the momentum equations. Three case studies were examined that (1) estimated fluid flow velocities of methane within the low-permeability Upper Jurassic Haynesville Formation, (2) defined permeability-based flow units to evaluate saline formations for long-term geologic carbon sequestration, and (3) calculated the migration distance of carbon dioxide plumes at the Decatur, Illinois injection and sequestration project.

Multidisciplinary approach in determining the best zone to land a Haynesville horizontal well

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.

Geologic analysis of the Upper Jurassic Haynesville Shale in east Texas and west Louisiana: Reply

The Upper Jurassic Haynesville Shale is currently regarded as one of the most prolific emerging shale-gas plays in the continental United States. It has estimated play resources of several hundred trillion cubic feet and per-well reserves estimated as much as 7.5 bcf. The reservoir spans more than 16 counties along the boundary of eastern Texas and western Louisiana. Although this basin has a long history of exploration and analysis of its Mesozoic section, a comprehensive subsurface study characterizing the Haynesville Shale has not been conducted. This article is the first to address the structural setting, stratigraphy, depositional environment and facies, fracturing, and production challenges of the Haynesville shale-gas play. Basement structures and salt movement influenced carbonate and siliciclastic sedimentation associated with the opening of the Gulf of Mexico. The Haynesville Shale is an organic- and carbonate-rich mudrock that was deposited in a deep partly euxinic and anoxic basin during the Kimmeridgian to the early Tithonian, related to a second-order transgression that deposited organic-rich black shales worldwide. The Haynesville Basin was surrounded by carbonate shelves of the Smackover and Haynesville lime Louark sequence in the north and west. Several rivers supplied sand and mud from the northwest, north, and northeast into the basin. Haynesville mudrocks contain a spectrum of facies ranging from bioturbated calcareous mudstone, laminated calcareous mudstone, and silty peloidal siliceous mudstone, to unlaminated siliceous organic-rich mudstone. Framboidal to colloidal pyrite is variably present in the form of concretions, laminae, and individual framboids and replaces calcite cement and mollusk shells. Haynesville reservoirs are characterized by overpressuring, porosity averaging 8 to 12%, Sw of 20 to 30%, nanodarcy permeabilities, reservoir thickness of 200 to 300 ft (70 to100 m), and initial production of as much as 30 mmcf/day. Reservoir depth ranges from 9000 to 14,000 ft (3000 to 4700 m), and lateral drilling distances are 3000 to 5000 ft (1000 to 1700 m). Typical Haynesville wells exhibit a steeper decline curve (80% in the first year) than other shale-gas plays, which is attributed to a very high overpressure.

Geologic analysis of the Upper Jurassic Haynesville Shale in east Texas and west Louisiana: Discussion

Hammes et al. (2011) provide an excellent technical compilation of the geology of the Haynesville shale-gas play in east Texas and west Louisiana. However, their citation crediting Chesapeake Energy Corporation solely with the commercial discovery and naming the play is poorly founded. The article cited (Durham, 2008) does not support that conclusion beyond the fact that Chesapeake was one of the first to announce the play. Furthermore, Durham's article in the AAPG Explorer did not attempt to document the discovery of the play, but instead was an interview of companies who, at that time, had publicly announced their interest. Brittenham (2010, slide 9) presented the early history of Encana in the play, which predates the activities and announcements by Chesapeake and others. Hammes et al. (2011) also do not mention the significant potential of the mid-Bossier Shale (Brittenham, 2010, slides 16, 20, and 24) that overlies the Haynesville Shale over much of the area mapped by Hammes et al. A summary of the events and timelines from publicly available data sources (IHS Energy) illustrates that, remarkably, at least three companies had an early knowledge of the play, drilled wells in vastly separate areas, and had early well-production test data with sufficient gas flow …

Three-dimensional pore networks and transport properties of a shale gas formation determined from focused ion beam serial imaging

Three-dimensional pore network reconstructions of mudstone properties are made using dual focused ion beam-scanning electron microscopy (FIB-SEM). Samples of Jurassic Haynesville Formation mudstone are examined with FIB-SEM and image analysis to determine pore properties, topology, and tortuosity. Resolvable pore morphologies (>~10 nm) include large slit-like pores between clay aggregates and smaller pores in strain shadows surrounding larger clastic grains. Mercury injection capillary pressure (MICP) data suggest a dominant 1–10 nm or less size of pores barely resolvable by FIB-SEM imaging. Computational fluid dynamics modelling is used to calculate single phase permeability of the larger pore networks on the order of a few nanodarcys (which compare favourably with core-scale permeability tests). This suggests a pore hierarchy wherein permeability may be limited by connected networks of inter-aggregate pores larger than about 20 nm, while MICP results reflect smaller connected networks of pores residing in the clay matrix. [Received: May 12, 2011; Accepted: September 14, 2011]

Haynesville and Bossier mudrocks: A facies and sequence stratigraphic investigation, East Texas and Louisiana, USA

Upper Jurassic Haynesville and Bossier shale-gas plays of the northwestern Gulf of Mexico (GOM) Basin produce from organic-rich, marine transgressive to highstand mudrocks within mixed carbonate-clastic depositional systems. Modern wireline-log suites from ∼200 deep wells were used for detailed correlations, and 10 + cores throughout the upper Kimmeridgian to lower Tithonian basin were incorporated into detailed facies, stratigraphic, and lithologic analyses. The Haynesville Shale lies within a 2nd-order transgressive systems tract (TST) that encompasses back-stepping ramp carbonates (proximal) and marine shales (distal) below a maximum flooding surface (MFS). This shale onlaps retrogradational carbonates and basement highs and is capped by the 2nd-order MFS. Bossier shales and local sandstones prograde basinward above the Haynesville shale and downlap the 2nd-order MFS. They grade upward and updip into the thick, highstand systems tract (HST), fluvio-deltaic sandstones of the Cotton Valley Group. Distally, organic-rich facies developed in restricted Bossier environments, creating another productive gas-shale opportunity. Several preexisting basement highs in the south and carbonate platforms in the northwest and west restrict and partition the basin, thus influencing deposition of highly organic versus nonorganic and siliciclastic-dominated versus carbonate-dominated lithologies. Haynesville and Bossier shales each compose three upward-coarsening cycles that probably represent 3rd-order sequences within the larger 2nd-order TST and early HST, respectively. Most of the three Bossier 3rd-order cycles are dominated by varying amounts of siliciclastics. Deposition of the Haynesville mudrocks occurred below storm-wave base under mostly dysoxic conditionsm allowing settlement of benthic bivalve communities and bioturbating organisms and oscillating periodically to more anoxic conditions on the seafloor. However, most of the sparse faunae found in these mudrocks are of planktonic origin. Bossier mudrocks exhibited more oxygenated and clastic-rich lithologies related to progradation of the clastic shoreline and sea-level highstand. Knowledge of lithologic, stratigraphic, geochemical, and faunal variations across mudrock basins needs to be detailed so that shale-gas basins might be successfully explored.

Geologic analysis of the Upper Jurassic Haynesville Shale in east Texas and west Louisiana

Geologic analysis of the Upper Jurassic Haynesville Shale in east Texas and west Louisiana

Sand thickness prediction from 3D seismic data: A case study of the Upper Jurassic Frisco City Sand of southwest Alabama

Discovery of oil at Frisco City Field in 1986 opened up a new play in the Upper Jurassic Haynesville Formation, Monroe County, southwest Alabama. (Figure 1). The Haynesville play, now in its second decade, has expanded to include 22 fields. There are two main productive areas: Conecuh Ridge in southern Monroe County and Covington High in southern Covington County. To date, these fields have produced approximately 22 million bls of oil and 33.6 billion ft3 of gas. Discoveries are linked to basement paleohighs that are part of the updip basement structure trend of the eastern Gulf. Reservoirs are found in structural traps, basement-cored anticlines, and faulted anticlines. There are also combination structural-stratigraphic traps in which the Haynesville Sand pinches out on the flanks of basement highs. Figure 1. Regional map of southwest Alabama showing major structural features and location of Frisco City Field (modified after Mink and Mancini, 1995). Essential geologic factors associated with Haynesville fields are: Haynesville Formation (Figure 2) can be divided into an upper (unnamed) member and the lower Buckner anhydrite member. The Haynesville conformably overlies the Smackover Formation. If the Smack-over is absent, it overlies basement rocks. The Haynesville is conformably overlain by the Upper Jurassic/Lower Cretaceous Cotton Valley Group. Figure 2. Jurassic stratigraphy and schematic cross-section of Monroe County, Alabama. The only upper Haynesville members found to be productive include the Haynesville, Frisco City, Megargel, and Baas reservoirs. The Haynesville reservoirs are concentrated in the Covington High area. The Frisco City, Megargel, and Baas reservoirs are on Conecuh Ridge. The Frisco City Sand, the most prolific …

ABSTRACT: A Method for Predicting Sand Thickness from 3-D Seismic, Upper Jurassic Frisco City Sand, Monroe County, Alabama

Abstract As exploration for Upper Jurassic Haynesville Formation reservoirs in southwest Alabama enters a mature phase and continues into a second decade, new predictive techniques are needed to expand the play beyond the current producing areas. In addition, new methodologies will play a key role in the successful implementation of secondary recovery projects in the existing fields of this prolific oil trend. A critical element in the exploration and development of Haynesville objectives is predicting reservoir thickness. Within this trend, Haynesville sandstones demonstrate variable thickness. This is a result of a range of depositional morphologies within the context of regional tectonics. An integrated 3D seismic and subsurface evaluation of three fields productive from the Frisco City Sand member of the Haynesville Formation in Monroe County, Alabama resulted in the development of a methodology to accurately determine the thickness variations of this reservoir. In concert with knowledge of depositional patterns and local structure, this quantitative technique can be carried beyond the fields studied and used regionally as an exploration tool, as well as locally in aiding exploitation and enhanced recovery projects in existent Haynesville fields.

Sequence-Keyed, High-Resolutlon Reservoir Zonation of Middle Jurassic Haynesville Ramp Carbonates in the Gladewater Field, East Texas Salt Basin : ABSTRACTS

Sequence-Keyed, High-Resolutlon Reservoir Zonation of Middle Jurassic Haynesville Ramp Carbonates in the Gladewater Field, East Texas Salt Basin : ABSTRACTS

High Resolution Reservoir Architecture of Late Jurassic Haynesville Ramp Carbonates in the Gladewater Field, East Texas Salt Basin: ABSTRACT

The East Texas Salt Basin contains numerous gas fields within Upper Jurassic Haynesville ramp-complex reservoirs. A sequenced-keyed, high-resolution zonation scheme was developed for the Haynesville Formation in Gladewater field by integrating core description, well-log, seismic, porosity and permeability data. The Haynesville at Gladewater represents a high-energy ramp system, localized on paleotopographic highs induced by diapirism of Callovian Age Salt (Louann). Ramp crest grainstones serve as reservoirs. We have mapped the distribution of reservoir facies within a hierarchy of upward-shallowing parasequences grouped into low-frequency sequences. The vertical stacking patterns of parasequences and sequences reflect the interplay of eustasy, sediment accumulation patterns, and local subsidence (including salt movement and compaction). In this study we draw on regional relations from analogous, Jurassic systems in Mexico to constrain the stratigraphic architecture, age model, and facies model. Additionally, salt-cored Holocene, grain-rich shoals from the Persian Gulf provide excellent facies analogs. The result is a new high-resolution analysis of reservoir architecture at a parasequence scale that links reservoir facies to depositional facies. The new stratigraphy scheme demonstrates that different geographic portions of the field have markedly distinct reservoir intervals, both in terms of total pay and the sequence-stratigraphic interval within which it occurs. Results from thismore » study are used to evaluate infill drill well potential, in well planning, for updating reservoir models, and in refining field reserve estimates.« less

Lower Cretaceous and Upper Jurassic Oil Reservoirs of the Updip Basement Structure Play: Southwest Alabama: ABSTRACT

Exploration for Lower Cretaceous and Upper Jurassic reservoirs associated with updip basement structures currently is the most active exploratory oil play in Alabama. High initial flow rates, on the order of hundreds to thousands of barrels of oil per day, are commonly encountered at depths between 8,200 and 14,500 feet. Fifty-one fields have been established and 25 million barrels of oil have been produced from these fields developed in Lower Cretaceous Hosston and Upper Jurassic Haynesville, Smackover, and Norphlet reservoirs. Production from Smackover carbonates began at Toxey field in 1967 and from Haynesville sandstones at Frisco City field in 1986. As of September 1994, Smackover wells averaged 88 barrels of oil per day and Haynesville wells averaged 284 barrels of oil per day. In 1994, production was established in the Norphlet at North Excel field and in the Hosston at Pleasant Home field. Reservoirs in the updip basement structure play cluster in three distinct areas; (1) a western area on the Choctaw ridge complex, (2) a central area on the Conecuh ridge complex, and (3) an eastern area in the Conecuh embayment. Reservoir lithologies include Smackover limestones and dolostones and Hosston, Haynesville, Smackover, and Norphlet sandstones. Hydrocarbon traps are structural more » or combination traps where reservoirs occur on the flanks or over the crests of basement palohighs. An understanding of the complex reservoir properties and trap relationships is the key to successful discovery and development of Lower Cretaceous and Upper Jurassic oil reservoirs of the updip basement structure play of southwest Alabama. « less

Controls on the Deposition of the Upper Jurassic Haynesville Formation, Clarke County, Southwestern Alabama: ABSTRACT

Controls on the Deposition of the Upper Jurassic Haynesville Formation, Clarke County, Southwestern Alabama: ABSTRACT

Petroleum Source Rock Potential of Mesozoic Condensed Section Deposits in Southwestern Alabama

Because condensed section deposits in carbonates and siliclastics are generally fine-grained lithologies often containing relatively high concentrations of organic matter, these sediments have the potential to be petroleum source rocks if buried under conditions favorable for hydrocarbon generation. In the Mesozoic deposits of southwestern Alabama, only the Upper Jurassic Smackover carbonate mudstones of the condensed section of the LZAGC-4.1 cycle have realized their potential as hydrocarbon source rocks. These carbonate mudstones contain organic carbon concentrations of algal and amorphous kerogen of up to 1.7% and have thermal alteration indices of 2- to 3+. The Upper Cretaceous Tuscaloosa marine claystones of the condensed section of the UZAGC-2.5 cycle are rich (up to 2.9%) in herbaceous and amorphous organic matter but have not been subjected to burial conditions favorable for hydrocarbon generation. The Jurassic Pine Hill/Norphlet black shales of the condensed section of the LZAGC-3.1 cycle and the Upper Jurassic Haynesville carbonate mudstones of the condensed section of the LZAGC-4.2 cycle are low (0.1%) in organic carbon. Although condensed sections within depositional sequences should have the highest source rock potential, specific environmental, preservational, and/or burial history conditions within a particular basin will dictate whether or not the potential is realized as evidencedmore » by the condensed sections of the Mesozoic depositional sequences in southwestern Alabama. Therefore, petroleum geologists can use sequence stratigraphy to identify potential source rocks; however, only through geochemical analyses can the quality of these potential source rocks be determined.« less

Depositional Setting of the Jurassic Haynesville Seismic Sequence in the Apalachicola Basin, Northeastern Gulf of Mexico: ABSTRACT

Seismic and well data from the northeastern Gulf of Mexico were used to define the seismic stratigraphy, geologic history, and depositional setting of the Jurassic (Kimmeridgian) Haynesville sequence in the Apalachicola basin. The data show that Haynesville clastic sedimentation updip was coeval with Haynesville carbonate deposition downdip. The regional Jurassic seismic stratigraphic framework includes, in ascending order, the Louann Salt Norphlet-Smackover, Haynesville, and Cotton Valley sequences. In the vicinity of Destin dome, wells have penetrated Haynesville sandstones, shales, and anhydrites. These clastics correlate with low amplitude, low-continuity reflections that characterize the Haynesville over a broad area updip. Similar reflections within the overlying (Tithonian-earliest Berriasian) Cotton Valley clastic sequence make seismic definition of the top Haynesville sequence boundary difficult updip. As Haynesville clastics are replaced by carbonates downdip, a high amplitude reflection marks the top of the sequence. Haynesville carbonates conformably overlie (Oxfordian) Smackover carbonates in the basin center, and the lower sequence boundary cannot be defined where disrupted by growth faults associated with early movement of the (Callovian ) Louann Salt. Sigmoid clinoforms document Haynesville shelf margin development Seismic facies also include oblique clinoforms that prograde eastward into the basin from the Southern Platform and Middle Ground Arch. No wellsmore » penetrate this facies. Mapping of the seismic facies and correlation with well data suggest a depositional setting for the Haynesville sequence in which influx of terrigenous clastics probably derived from adjacent land areas to the north and northeast filled a broad lagoon behind a carbonate shelf margin.« less

Deep-burial microporosity in upper Jurassic Haynesville oolitic grainstones, East Texas

Secondary micromoldic porosity generated during deep-burial diagenesis occurs pervasively in Upper Jurassic Haynesville oolitic grainstones in East Texas and constitutes the major pore type in these gas reservoirs. Petrographic and geochemical relationships establish that development of this microporosity postdates emplacement of bitumen and most pressure solution fabrics in the reservoir grainstones. Microporosity development is strictly controlled by depositional texture and is restricted to either active shoal complex grainstones or thicker grainstones shed downramp by storm processes. Haynesville diagenetic and porosity relationships are consistent along the entire length of the east flank of the East Texas Basin, a distance greater than 100 km; identical relationships have also been observed along the west flank of this basin. Haynesville micromoldic porosity development is confined principally to ooids but also occurs in normally “stable” calcitic skeletal grains like oysters. Resultant micropores are a few microns across or less; complete dissolution of ooids to form oomoldic macroporosity is not observed in Haynesville limestones. Nearly all primary porosity in the Haynesville is now occluded by carbonate cement. Confirmation of a late, deep-burial origin for Haynesville secondary microporosity is based on physical relationships observed in numerous cores, regional petrography and geochemical data. Collectively, these observations demonstrate that Haynesville sediments were never locally or regionally exposed to freshwater but have undergone progressive burial diagenesis punctuated by a major late dissolution event which created the microporosity. Key observations which support Haynesville deep-burial microporosity development include: (1) petrographic relationships which demonstrate microporosity developed after emplacement of bitumen; (2) lack of subaerial exposure features in core, both atop shoal complexes and at the contact between the Haynesville and Bossier sequences; (3) absence of freshwater porosity fabrics; (4) lack of precompactional freshwater cements; (6) pervasive pressure solution in the microporous grainstones, including extensive grain interpenetration; (6) preservation of abundant microporosity directly adjacent to pressure solution seams in porous grainstones; (7) development of identical microporosities in mineralogically stable calcitic grains which rarely leach in freshwater; (8) microporosity development which postdates formation and cementation of fractures in the reservoir facies; and (9) calcite cements occluding primary porosity whose geochemical attributes are inconsistent with precipitation from freshwater but are consistent with a burial origin. This regional, core-based case study reveals that the contact between the Haynesville and overlying Bossier Shale is a marine “drowning unconformity” Physical, petrographic and geochemical evidence for regional subaerial exposure at the end of Haynesville deposition, due to a eustatic fall in sea level, is not present, questioning the validity of interpreting local or global sea level history from seismic and well log data in the absence of critical core control.

Prolific Overton Field Gas Reservoirs Within Large Transverse Oolite Shoals, Upper Jurassic Haynesville, Eastern Margin of East Texas Basin: ABSTRACT

Prolific Overton Field Gas Reservoirs Within Large Transverse Oolite Shoals, Upper Jurassic Haynesville, Eastern Margin of East Texas Basin: ABSTRACT

Jurassic Geology of Alabama and Florida Panhandle: ABSTRACT

Jurassic sedimentation in the area reflects the influence of numerous Appalachian structural salients. These features include the Pensacola arch, Chattahoochee arch, Brevard anticline, and the southwest extension of the Appalachian structural front, as well as several pre-Jurassic igneous plugs. A great influx of clastic material invaded the seaward margins of these structures, obliterating recognized formation boundaries in the Late Jurassic Norphlet, Smackover, and Haynesville Formations. An anhydrite member of the Louann Salt, previously unnamed, was found in wells from Clarke, Monroe, and Wilcox Counties. This anhydrite, the Pine Hill Member, is at the top of the Louann Salt where salt is present and reaches a maximum recognized thickness of 210 ft. The Norphlet of Alabama is typically a red sandstone or conglomerate containing igneous pebbles, anhydrite, and minor amounts of shale. In much of the area it grades upward into a gray neritic sandstone which is believed to be equivalent to the Smackover. The Norphlet-Smackover contact in this facies cannot be distinguished but the upper gray sandstone is considered to be a good exploration target. In Choctaw and northern Washington Counties, typical Smackover and Norphlet sedimentary rocks can be recognized. In this area the oolitic facies of the upper Smackover is a major objective, with production established at Toxey and Choctaw Ridge fields. The Tombigbee depression, a depocenter for Jurassic sediments, was so named because the axis of this low follows the Tombigbee River along the east side of Washington County. During the time of Haynesville deposition this depression received large quantities of anhydrite and salt. On the northeast along the shoreward margin of the evaporites, a shoal facies developed in a relatively narrow NW-SE trend. This facies has a major exploration potential. Cotton Valley clastic rocks include sandstone and conglomerate typical of the Schuler facies of Mississippi. Igneous pebbles also are common. Seaward, the Dorcheat facies is present, and with it a more favorable environment for oil accumulation. This paper is not so much a documentation of the presently recognized Jurassic sediments as it is an interpretation of the projected facies and environments based on geologic concepts. Alabama and panhandle Florida will become important areas of Jurassic production in the near future. End_of_Article - Last_Page 1833------------