SPE 64281
Hydrodynamics in the Queensland Sector of the Cooper/Eromanga Basins: Identifying Non-Conventional Exploration Plays Using Water Pressure and Chemistry Data Webster M.A.*, Brew J., Grimison A.G.*
* Santos Ltd. Copyright 2000, Society of Petroleum Engineers Inc. As exploration programmes in these basins mature and reserve This paper was prepared for presentation at the SPE Asia Pacific Oil and Gas Conference and additions from conventional plays reach a plateau, Exhibition held in Brisbane, Australia, 16–18 October 2000. complementary or alternative techniques are required to This paper was selected for presentation by an SPE Program Committee following review of identify new exploration plays and non-conventional traps and information contained in an abstract submitted by the author(s). Contents of the paper, as presented, have not been reviewed by the Society of Petroleum Engineers and are subject to to provide insights into the petroleum systems operating correction by the author(s). The material, as presented, does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Papers presented at within these basins. Hydrodynamics is one such technique by SPE meetings are subject to publication review by Editorial Committees of the Society of which water pressure and chemistry data can be used to Petroleum Engineers. Electronic reproduction, distribution, or storage of any part of this paper for commercial purposes without the written consent of the Society of Petroleum Engineers is identify flow barriers, which may reflect hydrocarbon traps, prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous and flow conduits, which are likely migration fairways and acknowledgment of where and by whom the paper was presented. Write Librarian, SPE, P.O. areas of elevated seal risk. The technique provides a tool for Box 833836, Richardson, TX 75083-3836, U.S.A., fax 01-972-952-9435. evaluating the relative effectiveness of inter-formational and intra-formational sealing lithologies, which can then be Abstract applied in exploration risk assessment and particularly in the Analysis of water chemistry and pressure data from the ranking of stratigraphic leads and prospects. Queensland sector of the Cooper and Eromanga Basins This paper summarises results of a review of water indicates that two regional fluid flow systems are operating chemistry and pressure data from the most commercially within these basins. In the Eromanga Basin (Jurassic– significant reservoirs in the Eromanga and Cooper Basins in Cretaceous) a southwestward and descending open flow Southwest Queensland (Figs. 1 & 2). Water analyses are system is evident, driven by the topographically induced Great available for samples collected during drillstem tests or field Artesian Basin hydrodynamic regime. In the underlying production; these data have been screened to eliminate Cooper Basin (Upper Carboniferous–Triassic) a closed system samples contaminated with drilling or completion fluids. is reflected by overpressuring and ascending flow out of each Aquifer pressure measurements are available from drill stem of the major Permian troughs. Where the two systems interact test data or wireline (RFT or MDT) data; the pressure data and equilibrate, mixing of formation waters from Permian and have been screened to eliminate anomalies that are the result Jurassic reservoirs is apparent in water chemistry data and of hydrocarbon effects or sampling errors (supercharging, seal potentiometric surface minima can be identified in vertical failures etc). The data have been mapped both areally and pressure profiles. stratigraphically to identify directions and magnitude of fluid The water chemistry and pressure data have been used to flow within and between major flow units. identify hydraulic baffles within the Permian and Jurassic sequences. These barriers are likely to provide effective lateral Regional Setting or vertical seals and, once identified, can be targeted in The Eromanga Basin is one of three Mesozoic basins that regional mapping projects to identify potential stratigraphic together make up the Great Artesian Basin (GAB), an active traps. In addition to the potential exploration applications, groundwater system that covers an area of approximately 1.7 regional hydrodynamic databases are also valuable in million sq km, or one-fifth of the Australian continent (Fig. 1). petrophysical evaluations, by providing estimates of water The sedimentary sequence within the GAB is up to 3000m resistivity in areas with poor well control, and for estimating thick (Fig. 3). The Cooper Basin, a Permo-Triassic intra- field limits when the only available pressure data are from cratonic basin, covers an area of approximately 153,000 sq km hydrocarbon columns within crestal wells. and underlies the Eromanga Basin in the central portion of the GAB (Fig. 1). The Permo-Triassic sequence is up to 1500m Introduction thick and includes numerous shales and coals, deposited in Exploration programmes in the Cooper and Eromanga Basins lacustrine and fluvio-deltaic settings, which provide effective have historically relied upon 2D, and more recently 3D, capillary seals for multiple, stacked gas columns in many seismic data for the identification of potential structural traps. 2 WEBSTER M, BREW J, GRIMISON A SPE 64281 fields. Many of these units are potential seals for stratigraphic portion of the Cooper basin and flushing of Cooper basin traps where they onlap intra-basinal basement highs or brines by topography driven flow during the Tertiary9. downlap regional unconformities. Hydrodynamics enables an This paper presents data from oil and gas exploration, assessment to be made of the relative quality and effectiveness appraisal and development wells in Southwest Queensland of these units as hydraulic barriers. that confirm the GAB hydrodynamic flow is transmitted into The hydrogeology and hydrochemistry of the GAB have the underlying Cooper Basin. The results confirm that water been described in numerous publications 1-6. The basin chemistry and pressure data can be used to identify and map comprises a multi-layered confined aquifer system, with flow conduits and barriers within and between hydrocarbon aquifers in continental quartzose sandstones of Triassic, reservoirs in these basins. Jurassic and Cretaceous age. The major confining beds are Cretaceous marine mudstones of the Wallumbilla to Lower Water Chemistry Mackunda Formations 1,7 (Fig. 3). There are two main aquifer Approximately 630 water analyses are available for samples systems: a Cretaceous aquifer, which includes sandstones collected during drillstem tests and production in the within the Winton and Mackunda Formations, and a Jurassic– reservoirs of interest (Patchawarra, Toolachee, Epsilon in the lower Cretaceous system, which includes sandstones in the Cooper Basin and Precipice/Basal Jurassic and Hutton Precipice, Hutton, Adori and Cadna-owie Formations (Figs. 3 Formations in the Eromanga Basin, Fig. 3). These analyses -5). Waters enter these systems along the western slopes of the have been subjected to a series of standard industry screening Great Dividing Range, where the aquifers crop out, and to a criteria 10 designed to identify erroneous laboratory data and lesser degree along the western margin of the basin (Fig 4). contaminants derived from drilling fluids, water cushions, The waters travel for distances of up to 1200 km before being completion fluids, or condensation. Of this dataset, only 125 discharged along the southwestern and southern margins from samples (25%) are interpreted to represent ‘clean’ formation approximately 600 artesian springs that are associated with waters, highlighting the issue of formation invasion during the faulting and stratigraphic terminations in these areas. Flow drilling process and the difficulty in obtaining representative velocities are in the order of 1 – 5 m/yr and residence time for formation fluid samples. The range and average of Total the waters, calculated from the flow velocities and from Dissolved Solids (TDS) measurements for each reservoir are isotope data, is between 10 000 and 1.4 million years 2,3. The summarised as Table 1. Data can also be displayed as Stiff present hydrodynamic regime is interpreted to have been diagrams, which are used to characterise the chemical initiated in the early Cretaceous and modified during Plio- fingerprint of waters from each formation. Type Stiff diagrams Pleistocene tectonism when the eastern margin was uplifted to for the Permian Patchawarra Formation and the Jurassic form a broad syncline and the aquifers were elevated to their Hutton Formation are shown as Figure 6. The Eromanga current position 500 – 700m above sea level (Fig. 5). waters are characterised by their low salinity (Na & Cl) and Previous hydrogeological work has focussed primarily on high HCO3 content, reflecting a component of meteoric the water resources of the GAB, which have been exploited waters. In contrast, Permian waters from the Patchawarra since 1878. Some 30,000 shallow water bores have been Formation are characterised by higher Na and Cl drilled into the Cretaceous aquifer system, and approximately concentrations and low HCO3 content. 4700 into the Jurassic–lower Cretaceous system. The Hydrochemistry maps for the Hutton and Patchawarra potentiometric surface of the Cretaceous system has always Formations are included as Figures 7 & 8. The Hutton samples been below ground level, and wells tapping these aquifers are show consistent, low TDS profiles, particularly in the consequently non-flowing artesian bores that are usually northeast where TDS levels are <1100 mg/l, and high HCO3 equipped with windmill-operated pumps. The potentiometric concentrations. Similarly, the Patchawarra Formation samples surface of the deeper Jurassic-lower Cretaceous aquifer system display a characteristic profile with higher Na and Cl is above ground level, hence wells drilled into these reservoirs concentrations but low HCO3. There are several anomalous are naturally flowing artesian bores 4. The potential impact of samples in the Patchawarra dataset, including a sample from the GAB hydrodynamic flow in the Eromanga Basin Wackett-8, in an area of significant faulting on the flank of the Petroleum System has been previously reviewed in terms of Wackett high. the implications for petroleum migration, tilted field contacts The hydrochemistry map for the Toolachee Formation or flushing of oil accumulations within Jurassic and (Fig. 9) indicates Jurassic water signatures around the Central Cretaceous reservoirs 5,6. Some interflow with underlying Ridge and on the flanks of the Nappamerri Trough; basins has been inferred from water chemistry data 6,8. Toupin Patchawarra water signatures are apparent elsewhere in the et al 9 published results of finite-element modelling of the Toolachee system. These data suggest some mixing of hydrology of the Cooper and Eromanga Basins, focussing on Jurassic and Permian waters where the Triassic seals are the development of topography and compaction driven eroded and thin, or where the Permian and Jurassic reservoirs groundwater flow systems and their role in heat redistribution, are in fault communication. petroleum generation and oil and brine migration during basin evolution. Their models indicate hydraulic communication between the Cooper and Eromanga basins over the southern HYDRODYNAMICS IN THE QUEENSLAND SECTOR OF THE COOPER/EROMANGA BASINS: SPE 64281 IDENTIFYING NON-CONVENTIONAL EXPLORATION PLAYS USING PRESSURE AND WATER CHEMISTRY DATA 3
Aquifer Pressures from wells drilled prior to and post production startup, and Theory. The principles and applications of hydrodynamics in indicate that production-related pressure depletion is petroleum exploration are well documented in previous significant only in close proximity to fields. Most of the publications 11,12. The underlying principle in hydrodynamics exploration and appraisal wells in the Queensland sector of the is that subsurface fluid movement occurs in response to Cooper Basin were drilled prior to any production in the area potential energy differences, and that flow is directed from and are thus unaffected. regions of high to low potential energy. The magnitude of the potential energy differential and the permeability of flow units Potentiometric Surface Calculations. A key assumption in the (aquifers) and flow barriers (aquitards and aquicludes) control calculation of potentiometric surface elevations is the average the rate of flow within and between flow units. The density of water in the column, which requires knowledge of Potentiometric Surface Elevation (PSE) is an expression of the variations in water density, both areally and stratigraphically. potential energy (or hydraulic head) at any point in the Formation waters in the Cooper and lower Eromanga Basin subsurface, and can be calculated from measured pore reservoirs occupy a relatively narrow range of salinities but pressures as follows: heat flow does vary significantly around the basins and impacts the density of waters at reservoir conditions (Fig. 11). PSE = Z+P/Dw Geothermal gradients, derived from extrapolated bottom hole temperature measurements and DST temperatures, have been where : PSE= Potentiometric Surface Elevation (ft) used to correct measured water densities to subsurface Z= Elevation of Pressure Measurement (ft ss) conditions, from which a water gradient at reservoir conditions P= Measured Aquifer Pressure (psia) can be extracted. Dw= Average Water Density Gradient (psi/ft) There are three commonly applied alternatives used to calculate a Potentiometric Surface Elevation. A Point Source Conversion factors are included as Table 2. Head is calculated by extrapolating the water gradient at reservoir conditions to atmospheric conditions; this technique Pressure Data. Aquifer pressures have been derived from introduces a significant error because it fails to account for the DST and RFT / MDT measurements in exploration, appraisal role of temperature. A Fresh Water Equivalent (FWE) Head and development wells. The database in the area of interest can be calculated by extrapolating a fresh water gradient from comprises approximately 1200 DSTs in the reservoirs under the point of measurement. An Environmental Head applies an review, of which around 145 are interpreted to be valid tests of integrated average of the water density variations through the water zones. RFT/MDT data in these reservoirs are available water column and should be closest to the true head. For the for approximately 110 wells. DST data were graded according purposes of regional PSE mapping, a freshwater head is to the difference between final shut-in pressure and generally accurate up to a salinity of 25,000 mg/l TDS and can extrapolated reservoir pressure; the pressures were cross- be applied in basins where formation waters are relatively checked against the water chemistry database to ensure a fresh 11. pressure was derived for each valid water test. MDT data For this review, both FWE and Environmental heads were were similarly graded using mobility ratios, fluid gradients calculated, in both instances corrected for temperature (where multiple pressures were acquired within a sand) and variations with depth. Results are very similar, as would be log response, to confirm the pressures did not reflect expected with the low water salinities, and it is concluded that hydrocarbon effects. Pressure measurements from for the purposes of identifying regional hydrodynamic trends, development wells, obtained for reservoir management and either a temperature-corrected FWE or environmental head is showing clear pressure depletion related to production, were suitable in the Cooper / Eromanga Basins. excluded from the dataset. A summary Pressure / Elevation An example of an MDT dataset that clearly illustrates the plot for Toolachee Formation reservoirs, plotted against a hydrodynamic regime is provided by Wackett-8, an reference sea level hydrostatic reference gradient, is included appraisal/exploration well drilled on the southern flank of the as Figure 10. The plot illustrates the variation in pressure Wackett structure (Fig. 2) in 1997. Figure 12 is a summary of within the Toolachee Formation reservoirs at comparable MDT pressure measurements in water zones in the well. The depths, indicating a dynamic aquifer system. plot shows a distinct offset between points in the Jurassic Production Effects. As production effects will result in local Hutton sandstone and the Permian Toolachee reservoir, with a aquifer depletion, which could be confused with hydrologic smaller offset between the Toolachee and deeper Epsilon and flow, cumulative production figures for each flow unit were Patchawarra Formation reservoirs. A hydrostatic reference plotted on a chronological series of maps and checked when gradient, extrapolated from ground level, confirms that all selecting and interpreting pressure measurement. Oil reservoirs are overpressured relative to a hydrostatic regime, production did not commence from Eromanga Basin fields in verifying the hydrodynamic regime. A plot of the PSE for Southwest Queensland until 1984 and gas production from each reservoir against depth (Fig. 13) clearly shows the offsets Cooper Basin reservoirs in this area has only been significant in PSE between the different aquifers and is valuable in since 1994. MDT and DST data are available in most areas visually identifying aquitards in the system. The Hutton PSE is 4 WEBSTER M, BREW J, GRIMISON A SPE 64281 substantiated by a DST pressure from Wackett-1, drilled in and reflects downward flow from the Eromanga reservoirs. A 1978, prior to any production in the area. very steep gradient is mapped into the Nappamerri trough, Figure 14 is an example of a hydraulic barrier identified where data are available. This reflects regional overpressuring from MDT profiles in one of the Cooper Basin gas fields. Two (in some areas more than 2000 psi in excess of hydrostatic) gas columns are present in this field, one in the Toolachee and which is interpreted to be the consequence of volumetric upper Patchawarra reservoirs, and one in the lower expansion related to hydrocarbon generation and cracking in Patchawarra reservoirs. An offset in water gradients is evident the deep low permeability environment. above and below an intra-formational coal/shale unit within the Patchawarra Formation, confirming this unit is an effective Interpretation. The PSE and water chemistry data are capillary and hydraulic barrier. summarised as a regional cross section (Fig. 18) across the Maps of the PSE for the Hutton, Toolachee and major troughs and structural highs in the basin (Fig. 2). The Patchawarra Formations are included as Figures 15-17; similar pressure data indicate a Southwestward and downward flow maps have been constructed for other reservoirs in both the regime in the Eromanga basin sequence, driven by the Great Eromanga and Cooper Basin sequences. The Hutton Artesian Basin hydrodynamic regime. The highest Formation map clearly reflects the Great Artesian Basin potentiometric surface elevations within this sequence occur hydrodynamic flow regime, with a potentiometric gradient of within the lower Cretaceous Namur Sandstone (Fig. 3). This approximately .001215 (1:825) across the area, and flow open flow system is evident in many areas down to the potential from the Northeast to Southwest. The orientation Epsilon Formation, and in faulted areas down into the and magnitude of the potentiometric gradient in the Jurassic Patchawarra Formation. This is confirmed by widespread aquifer is in close agreement with published data derived from dilution (mixing) of the Toolachee Formation waters and by water bores4. Isopotential contours are evenly spaced in the the recovery of fresh Jurassic waters from Patchawarra north, indicating there are few barriers to flow. The Formation reservoirs in some wells e.g. Wackett-8. A closed isopotential contours converge south of the Central Ridge and ascending flow system is apparent in the Patchawarra mimic the form of the underlying Nappamerri Trough. PSE Formation in each of the Permian troughs and is interpreted to values indicate flow into the trough along the margins, reflect overpressuring related to gas generation and cracking. suggesting hydraulic communication along the flanks where A hydrostatic envelope is formed where these two systems the Nappamerri Formation (the Triassic seal separating equilibrate. This envelope occurs at various stratigraphic Permian and Jurassic reservoirs) is thin. Two potentiometric levels around the basin, and can be identified on MDT profiles lows are evident in the Naccowlah and Pallano areas. These in several wells. indicate convergent flow from surrounding areas and, to preserve material balance considerations, must be areas where Conclusions fluids are exiting this flow unit 11. Seismic data confirm the Hydrodynamics is a valid exploration tool in the Cooper and Nappamerri Group is thin or absent in these areas. These are Eromanga Basins. Water chemistry and aquifer pressure data therefore areas of hydraulic communication where Jurassic indicate that two regional flow systems are operating in these waters are entering the underlying Permian basin. Similarly, basins: a southwestward and downward open flow system in an enclosed potentiometric high in the Munkah area indicates the Eromanga basin, driven by the Great Artesian Basin flow into this unit from above or below (whichever has higher regime, and an ascending closed system in the Patchawarra potential energy). Formation in each of the major troughs. Flow barriers (seals) The PSE map for the Toolachee Formation (Fig. 16) and flow conduits (migration pathways) can be identified reveals a similar gradient, with the PSE decreasing from using these data, improving our ability to identify and map approximately 1000 ft in the Northeast to less than 200 ft at subtle stratigraphic traps and rank exploration opportunities on the South Australia border. Enclosed potentiometric highs are the basis of their relative seal risk. apparent on the Central ridge at Yanda and Wackett, with a large potentiometric low in the Ballatt area. A fault to the Acknowledgments northeast of Barrolka appears to be restricting flow but energy The authors wish to acknowledge the SWQ Unit parties is retained in a narrow flow path extending to Karmona. (Santos Ltd, Delhi Petroleum, Origin Energy and Oil Corridor-1 lies at the junction of these trends; a Toolachee Company of Australia) for their permission to publish these water sample from this well shows no evidence of mixing data. We also thank Natalie Pestana, Joe Reichman and Chris (Fig. 9), suggesting the change in flow direction reflects a Hill, who provided valuable reservoir engineering input, Ann barrier in this flow unit. The PSE map indicates flow into the Allen-Ankins and Jeff Bloye, who drafted the figures, and Nappamerri trough, as seen in the Hutton Formation. Claus Otto (CSIRO Petroleum) who acted as external advisor. In contrast, the map of the Patchawarra Formation (Fig 17) indicates flow is out of the Nappamerri Trough. Two References potentiometric highs are apparent on the Central Ridge, at 1. Habermahl, M.A.: “The Great Artesian Basin, Australia”. Bureau Wackett and Nockatunga. The Wackett anomaly is related to of Mineral Resources Journal of Australian Geology & the fresh water recovery in the Patchawarra Formation (Fig. 8) Geophysics v 5, pp 9-38 (1980). HYDRODYNAMICS IN THE QUEENSLAND SECTOR OF THE COOPER/EROMANGA BASINS: SPE 64281 IDENTIFYING NON-CONVENTIONAL EXPLORATION PLAYS USING PRESSURE AND WATER CHEMISTRY DATA 5
2. Habermahl, M.A. : “Regional Groundwater Movement, Hydrochemistry and Hydrocarbon Migration in the Eromanga Basin” in Gravestock, D.I., Moore P.S., Pitt G.M eds Contributions to the Geology and Hydrocarbon Potential of the Eromanga Basin : Geological Society of Australia Special Publication 12, pp 353 – 376 (1986) 3. Habermahl, M.A.: “Groundwater Movement and Hydrochemistry of the Great Artesian Basin, Australia” In Mesozoic Geology of the Eastern Australia Plate Conference. Geological Society of Australia Extended Abstracts 43, pp 228 – 236 (1996) 4. Habermahl, M.A., Lau, J.E.: “Hydrogeology of the Great Artesian Basin, Australia” Map at 1:2 500 000. Australian Geological Survey Organisation, Canberra. (1997) 5. Bowering, O.J.W. : “Hydrodynamics and Hydrocarbon Migration – a Model for the Eromanga Basin. APPEA (1982) 6. Williams, T., Moriarty, K.: “Hydrocarbon Flushing in the Eromanga basin – fact or fallacy?” In Gravestock, D.I., Moore P.S., Pitt G.M eds Contributions to the Geology and Hydrocarbon Potential of the Eromanga Basin : Geological Society of Australia Special Publication 12, pp 377 – 384 (1986) 7. Toupin, D.D.K.: “The Effect of Groundwater Flow Patterns in Evolving Intracratonic Sedimentary basins on Heat Flow and Petroleum generation” MSc (Hydrology) Thesis, University of New Hampshire (1993) 8. Youngs, B.C. : “The Hydrology of the Gidgealpa Formation of the Western and Central Cooper Basin” Geological Survey of South Australia Report of Investigations 43 (1975) 9. Toupin, D., Eadington, P.J., Person, M., Morin, P., Wieck, J., Warner, D. : “Petroleum Hydrogeology of the Cooper and Eromanga Basins, Australia: Some Insights from Mathematical Modelling and Fluid Inclusion data” AAPG Bulletin 81 (4), pp 577 – 603 (1997). 10. Johnson : “Water Analysis Interpretation”. Opus Petroleum Engineering, Calgary (1992) 11. Dahlberg, E.C. : “Applied Hydrodynamics in Petroleum Exploration”. Second edition, Springer-Verlag (1995) 12. Reid, H.W. : “Subsurface Pressures & Fluid Dynamics” Course Notes, Hugh W Reid & Associates Ltd (1997). 13. Schlumberger : Log Interpretation Principles / Applications (1989) 6 WEBSTER M, BREW J, GRIMISON A SPE 64281
Formation TDS (mg/l) Clean Samples Range Average Hutton 782 - 5523 2009 Basal Jurassic 1570 - 7300 3765 Toolachee 1920 - 11136 7514 Epsilon 5851 - 12306 9584 Patchawarra 4078 - 19243 14845
Table 1 : Water Salinity Data, Cooper / Eromanga Basins
To get Multiply By m ft 0.3048 kPa psi/ft 22.5 psi/m psi/ft 3.28 lb/gal psi/ft 19.3
Table 2 : Conversion Factors
500 km
CARPENTARIA BASIN NT
STUDY QLD AREA EROMANGA BASIN
COOPER BASIN SURAT BASIN Brisbane
SA NSW
Figure 1 : Location Map, Great Artesian Basin HYDRODYNAMICS IN THE QUEENSLAND SECTOR OF THE COOPER/EROMANGA BASINS: SPE 64281 IDENTIFYING NON-CONVENTIONAL EXPLORATION PLAYS USING PRESSURE AND WATER CHEMISTRY DATA 7
142° 144° Blackstump High 26°
WINDORAH ATP TROUGH 577P ATP 269P
ATP 299P
ARRABURY TROUGH
Innamincka ATP 267P Dome ATP 259P Ballera
NAPPAMERRI Wackett 8 TROUGH Jackson
ATP 267P
28°
50 km
Limit of Toolachee Formation Major Gas Field
Queensland New South Wales
Figure 2 – Structural Elements, Queensland Sector, Cooper / Eromanga Basins 8 WEBSTER M, BREW J, GRIMISON A SPE 64281
AGE LITHOSTRATIGRAPHY HYDROSTRATIGRAPHY
AQUIFERS
Confining Beds WINTON FM Confined Aquifers 100 MACKUNDA FM ALLARU MUDSTONE TOOLEBUC FM Confining Beds (Cretaceous) WALLUMBILLA FM 120
CADNA-OWIE FM Confined Aquifers (Lower Cretaceous) 140 MURTA / NAMUR SST
WESTBOURNE FM ADORI SST BIRKHEAD FM 160
HUTTON SST Confined Aquifers and Confining Beds (Jurassic) 180
BASAL JURASSIC FM
200
220 Confining Beds (Triassic)
NAPPAMERRI GROUP 240 Confined Aquifer (Triassic)
Confining Beds (Triassic)
260 TOOLACHEE FM.
DARALINGIE / ROSENEATH EPSILON / MURTEREE Confined Aquifers 280 and Confining Beds PATCHAWARRA FM (Permian)
TIRRAWARRA / MERRIMELIA FM
Figure 3 – Simplified Stratigraphic Column, Cooper / Eromanga Basin
Direction of groundwater flow Recharge area Spring Concentration of springs
300 km
Alice Springs EROMANGA BASIN
COOPER BASIN
Lake SURAT Brisbane Eyre BASIN
Lake Lake Frome Torrens
Figure 4 – Groundwater Flow, Great Artesian Basin (modified from Ref.3) HYDRODYNAMICS IN THE QUEENSLAND SECTOR OF THE COOPER/EROMANGA BASINS: SPE 64281 IDENTIFYING NON-CONVENTIONAL EXPLORATION PLAYS USING PRESSURE AND WATER CHEMISTRY DATA 9
SW DISCHARGE NE AREA RECHARGE AREA
Elevation Muloorina 1 Eastwood 1 Elevation (m) Kopperamona 2 Lycium 1 Merrimelia 3 Arrabury 1 Cumbroo 1 Leopardwood 1 (m) Cannawaukinna 1 Jennet 1 Merrimelia 1 Mt Howitt 1 Cothalow 1 Etonvale 1 Lake Lettie 1 Innamincka 1 Alberreck 1 Peachawarinna 2 Mulapula 1 Gidgealpa 1 Barrolka East 1 Canaway 1 Gilmore 1 Allandale 1 Packsaddle 1 500 500
Sea Sea Level C C C Level
-500 -500
-1000 -1000
-1500 -1500
-2000 -2000
Triassic -2500 -2500 C Cainozoic Confining Bed -3000 -3000 Permian Aquifer 0 50 100 COOPER Toolachee Formation -3500 BASIN -3500 Kilometres -4000 -4000
-4500 -4500
Figure 5 – Great Artesian Basin, Regional Cross Section (modified from Ref. 4)
Ion Concentration (Meq/l) 30 20 10 0 10 20 30 Na*10 Cl*10
K*10
Ca HCO3
Mg SO4 Eromanga Type Stiff Diagram
Ion Concentration (Meq/l) 30 20 10 0 10 20 30 Na*10 Cl*10
K*10
Ca HCO3
Mg SO4 Patchawarra Type Stiff Diagram
Figure 6 – Type Stiff Diagrams 10 WEBSTER M, BREW J, GRIMISON A SPE 64281
142° 144° 26°
WINDORAH TROUGH ATP ATP 269P 577P
ATP 259P ATP 299P
ARRABURY TROUGH
Innamincka ATP 267P Dome Ballera
NAPPAMERRI TROUGH Jackson 50 km
ATP 267P
28°
Limit of Toolachee Formation Major Gas Fields Stiff Diagram
Figure 7 – Hydrochemistry Map, Hutton Formation HYDRODYNAMICS IN THE QUEENSLAND SECTOR OF THE COOPER/EROMANGA BASINS: SPE 64281 IDENTIFYING NON-CONVENTIONAL EXPLORATION PLAYS USING PRESSURE AND WATER CHEMISTRY DATA 11
142° 144° 26°
WINDORAH TROUGH ATP ATP 269P 577P
ATP 259P ATP 299P
ARRABURY TROUGH
Innamincka ATP 267P Dome Ballera
NAPPAMERRI TROUGH Jackson 50 km
ATP 267P
28°
Limit of Patchawarra Formation Major Gas Fields Stiff Diagram
Figure 8 – Hydrochemistry Map, Patchawarra Formation 12 WEBSTER M, BREW J, GRIMISON A SPE 64281
142° 144° 26°
WINDORAH TROUGH ATP ATP 269P 577P
ATP 259P ATP 299P
ARRABURY TROUGH
Innamincka ATP 267P Dome Ballera
NAPPAMERRI TROUGH Jackson 50 km
ATP 267P
28°
Limit of Toolachee Formation Major Gas Fields Stiff Diagram
Figure 9 – Hydrochemistry Map, Toolachee Formation HYDRODYNAMICS IN THE QUEENSLAND SECTOR OF THE COOPER/EROMANGA BASINS: SPE 64281 IDENTIFYING NON-CONVENTIONAL EXPLORATION PLAYS USING PRESSURE AND WATER CHEMISTRY DATA 13
-4500
Toolachee DST’s -5000 Toolachee MDT’s Hydrostatic (SL) Reference Gradient -5500
-6000
-6500
-7000
-7500
-8000
-8500 2000 2500 3000 3500 4000 Reservoir Pressure P* (psia)
Figure 10 – Summary Pressure / Elevation Plot, Toolachee Formation
Temperature (°C) 25 50 100 150 200
1.2 Pressure
1.15
1.10
1.05
1.00
0.95
Range of Hutton and Permian Reservoir Conditions, SWQ, Cooper / Eromanga Basins
0.90
0.85 40 100 200 300 400 440 Temperature (°F)
Figure 11 – Water Density Nomograph (modified from Ref. 13) 14 WEBSTER M, BREW J, GRIMISON A SPE 64281
-5000 Hutton Toolachee Epsilon -5500 Patchawarra GL Hydrostatic
-6000
-6500
-7000 2000 2250 2500 2750 3000 3250 3500 Pressure (psia)
Figure 12 – Wackett-8 Summary MDT Data
-4000 Hutton Toolachee Epsilon -5000 Patchawarra
-6000
-7000
-8000 200 300 400 500 600 700 800 900 1000 PSE (ft)
Figure 13 – Wackett-8 PSE Plot HYDRODYNAMICS IN THE QUEENSLAND SECTOR OF THE COOPER/EROMANGA BASINS: SPE 64281 IDENTIFYING NON-CONVENTIONAL EXPLORATION PLAYS USING PRESSURE AND WATER CHEMISTRY DATA 15
-6600 Gas 0.08 psi/ft Well 2 RFT -6700 Well 5 RFT Well 4 RFT -6800 Toolachee & Upper Patchawarra Well 7 RFT Gas Column
-6900
-7000 Aquifer pressures in Toolachee & Upper Lower Patchawarra reservoirs Patchawarra -7100 Gas Column
Reference Water Gradients 0.426 psi/ft -7200
Higher aquifer -7300 pressure indicated in Lower Patchawarra reservoirs
-7400 3200 3300 3400 3500 Pressure (psia)
Figure 14 – Field Example of Hydraulic Barrier, Cooper Basin 16 WEBSTER M, BREW J, GRIMISON A SPE 64281
142° 144° 26°
WINDORAH TROUGH ATP ATP 269P 577P
ATP 259P
ARRABURY ATP 299P TROUGH
Innamincka ATP 267P Dome Ballera
Munkah
NAPPAMERRI Naccowlah TROUGH 50 km Pallano Jackson
ATP 267P
28°
Limit of Toolachee Major Gas Fields PSE (feet) Data Point
Figure 15 – Potentiometric Surface Elevation, Hutton Formation HYDRODYNAMICS IN THE QUEENSLAND SECTOR OF THE COOPER/EROMANGA BASINS: SPE 64281 IDENTIFYING NON-CONVENTIONAL EXPLORATION PLAYS USING PRESSURE AND WATER CHEMISTRY DATA 17
142° 144° 26°
WINDORAH TROUGH ATP ATP 269P 577P
ATP 259P
ARRABURY ATP 299P TROUGH Corridor
Karmona Innamincka ATP 267P Dome Ballera Ballat Yanda NAPPAMERRI TROUGH 50 km Jackson
ATP 267P
28°
Limit of Toolachee Major Gas Fields PSE (feet) Data Point
Figure 16 – Potentiometric Surface Elevation, Toolachee Formation 18 WEBSTER M, BREW J, GRIMISON A SPE 64281
142° 144° 26°
WINDORAH TROUGH ATP 577P ATP 269P
ATP 259P
ARRABURY ATP 299P TROUGH
Innamincka ATP 267P Dome Ballera
NAPPAMERRI Wackett TROUGH Jackson 50 km
ATP 267P
28°
Limit of Patchawarra Major Gas Fields PSE (feet) Data Point
Figure 17 – Potentiometric Surface Elevation, Patchawarra Formation HYDRODYNAMICS IN THE QUEENSLAND SECTOR OF THE COOPER/EROMANGA BASINS: SPE 64281 IDENTIFYING NON-CONVENTIONAL EXPLORATION PLAYS USING PRESSURE AND WATER CHEMISTRY DATA 19
Elevation BARYULAH CHALLUM WEST BEEREE (feet SS) BOWEN WINNINIA JUNO CHALLUM MACADAMA BARROLKA NE WHANTO
NAPPAMERRI TROUGH BARROLKA E -5000 E ARRABURY TROUGH WINDORAH TROUGH WAREENA H HIGH H L 498
-6000 E 480 H 590 800 420 L 414 L -7000 500 Hutton/ Basal Jurassic 780
458 P Nappamerri Group -8000 370 R* P2 518 1100 453 V 325 V4 P2 800+ R* -9000 720 BASEMENT P BASEMENT P2 Z W Z V4 R*
Z -10000 Birkhead Epsilon/Roseneath/Murteree BASEMENT Hutton / Basal Jurassic Patchawarra
-11000 Nappamerri Group PSE Isocontours (FWE in Permian Units) 0 10 20 Toolachee 325 Control Points Kilometres Flow Potential / Direction
Figure 18 – Summary Cross Section Illustrating Regional Flow Systems (refer to Figure 2 for location)