Pressure Buildup Test Results From Horizontal Wells in the Pearsall Field of the Austin Chalk

1990 ◽  
Author(s):  
G.J. Lichtenberger
Keyword(s):  
Horizontal Wells ◽  
Test Results ◽  
Pressure Buildup ◽  
Austin Chalk

The Austin Chalk: Simulation of Horizontal Wells in a Heterogeneous Formation

1990 ◽  
Author(s):  
G.C. Schnerk ◽  
C.N. Madeen
Keyword(s):  
Horizontal Wells ◽  
Austin Chalk ◽  
Heterogeneous Formation

Development of the Brookeland Field Austin Chalk Drilling Dual Lateral Horizontal Wells

1993 ◽  
Author(s):  
R.E. McMann ◽  
C.R. Lipp ◽  
C.K. Pruski ◽  
M.F. Cooney
Keyword(s):  
Horizontal Wells ◽  
Austin Chalk

Field Testing of the Flowback Technology for Multistage-Fractured Horizontal Wells: Test Results and Primary Interpretation of the Results

2020 ◽  
Author(s):  
Albert Vainshtein ◽  
Georgii Fisher ◽  
Sergei Boronin ◽  
Andrei Osiptsov ◽  
Ildar Faysullin ◽  
...  
Keyword(s):  
Horizontal Wells ◽  
Field Testing ◽  
Test Results ◽  
Fractured Horizontal Wells

Water Testing Technology Research and Application in Horizontal Well

2014 ◽  
Vol 1010-1012 ◽  
pp. 1754-1757
Author(s):  
Hong Jun Li
Keyword(s):  
Horizontal Well ◽  
Scientific Research ◽  
Horizontal Wells ◽  
Oil Fields ◽  
Test Results ◽  
Technology Research ◽  
Good Test ◽  
Water Testing ◽  
Liaohe Oilfield ◽  
Testing Technology

Now, water testing in horizontal well is still a worldwide problem, has not yet been mature and reliable technology is widely used in oil fields. Liaohe oilfield test center after three years of scientific research, has made some progress, developed a set of suitable technology for water testing in Liaohe oilfield horizontal wells, and to apply this technology to the water testing in oil wells, a good test results have been achieved.

Laboratory studies on fracturing of low-permeability soils

2001 ◽  
Vol 38 (2) ◽  
pp. 303-315 ◽  
Author(s):  
Marolo C Alfaro ◽  
Ron CK Wong
Keyword(s):  
Injection Pressure ◽  
Horizontal Wells ◽  
Tensile Failure ◽  
Low Permeability ◽  
Test Results ◽  
In Situ Remediation ◽  
Initial Fracture ◽  
Initiation Pressure ◽  
Stress Contrast

Hydraulic and pneumatic fracturing have been used to improve the effectiveness of most in situ remediation methods for contaminated sites underlain with unfavorable low-permeability soils. This paper presents results of a laboratory experimental investigation to characterize the mechanisms related to the initiation pressure and growth of fractures stimulated from vertical and horizontal wells. The mechanisms of fracture in low-permeability soils appeared to be of a tensile failure mechanism enhanced by the generation of pore pressure as the soil around the well was being sheared due to the radial-tangential stress difference imposed by the injected pressure. The impacts of initial fracture slots on fracture orientation and initiation pressure were also investigated. The test results have demonstrated that the presence of initial fracture slots could reduce the injection pressure required to initiate fracture in the well. The initial slot, however, did not necessarily control the orientation of the propagating fracture. The effect of imposed stresses in the soil was evaluated also and was found to influence the orientation and propagation of fracture. Smaller stress contrast favored multiple deviated fractures, whereas larger stress contrast favored distinct fractures.Key words: soil fracturing, laboratory test, low-permeability soil, fracture propagation.

Drilling and Production Aspects of Horizontal Wells in the Austin Chalk

1991 ◽  
Vol 43 (07) ◽  
pp. 773-779 ◽  
Author(s):  
B.A. Shelkholeslami ◽  
B.W. Schlottman ◽  
F.A. Seidel ◽  
D.M. Button
Keyword(s):  
Horizontal Wells ◽  
Austin Chalk

Drilling and Production Aspects of Horizontal Wells in the Austin Chalk: ABSTRACT

AAPG Bulletin ◽  
1990 ◽  
Vol 74 ◽  
Author(s):  
B. A. Sheikholeslami, B. W. Schlott
Keyword(s):  
Horizontal Wells ◽  
Austin Chalk

Specifying Lengths of Horizontal Wells in Fractured Reservoirs

2002 ◽  
Vol 5 (03) ◽  
pp. 266-272 ◽  
Author(s):  
Julia F.W. Gale
Keyword(s):  
Fractured Reservoirs ◽  
Horizontal Wells ◽  
Size Distributions ◽  
Aperture Size ◽  
Fracture Permeability ◽  
Site Specific ◽  
Fracture Systems ◽  
Austin Chalk ◽  
Opening Mode ◽  
Central Texas

Summary New methods have been developed to constrain optimal horizontal drilling distance in fractured reservoirs in which opening-mode fractures are dominant. Studies of opening-mode fractures in Austin Chalk outcrops and core reveal that open fractures are commonly clustered, with the distance between clusters ranging from approximately 1 m to more than 300 m, depending on the horizon in question. Aperture-size distributions follow power laws, and spacing-size distributions are negative logarithmic or log-normal. The aperture size at which fractures are open to fluids is variable and site-specific (0.14 to 11 mm). Scaling properties of fracture attributes were used to calculate fracture permeability and to constrain well-length fracture-permeability relationships. Fracture permeability depends on the scale of measurement; it has been determined at 9.2 darcies for 14 m of lower Austin Chalk core and 286 darcies for 300 m of upper Austin Chalk outcrop. Introduction The Upper Cretaceous Austin Chalk, which crops out in a swath across central Texas, is renowned as a horizontal play and is well documented as such.1,2 Most workers regard Austin Chalk reservoirs as being low-porosity, fractured reservoirs, although there is debate concerning the relative storage capacities of matrix vs. fractures. When drilling a horizontal well in a fractured reservoir, the usual aim is to intersect fractures that are capable of providing a conduit for fluid flow. Although many horizontal wells have been drilled in the Austin Chalk,3 there are still questions over where it is best to locate new operations and how to optimize three critical parameters: wellbore azimuth, vertical depth, and wellbore length.4 This paper focuses on the question of wellbore length, although information pertaining to azimuth and depth choices also has been obtained. The choice of wellbore length has, in the past, been guided by experience and by field rules established by the Texas Railroad Commission, whereby the length of wells is linked to the acreage allocation of proration units and the permissible producing rate.4 Although these guidelines are practical, they lack direct geological input. The aim of this contribution is to develop techniques in which well-length determination is based on direct observation of fracture systems in the Austin Chalk, in addition to the Texas Railroad Commission guidelines. The objective of the outcrop and core studies was to characterize the opening-mode fracture system. Aperture-size distribution, spacing-size distribution, and fracture fill were determined in each case, allowing characterization of the spatial architecture of large, open fractures. This approach enabled us to calculate fracture permeability for different well lengths and to constrain optimal drilling distance for horizontal wells. The relationship between opening-mode fractures and normal faults in the outcrop is documented, and the relative importance of fractures and faults to reservoir permeability is considered. The connectivity and vertical height of fractures, and their impact on permeability, are discussed. Study Areas Data are presented from two outcrop analogs: one is near Waxahachie, north central Texas (Grove Creek); the other is from McKinney Falls State Park, central Texas (McKinney Falls), and from two laterals of a horizontal core drilled by the Kinlaw Oil Corp. in Frio County, Pearsall field (Kinlaw core) (Fig. 1). This well is currently operated by BASA Resources Inc. Although this study relates to the Austin Chalk specifically, the techniques used are transferable and could be applied in other horizontal targets. Geology The Austin Chalk is variable in terms of mineralogy, texture, and stratigraphy in part because of the effect of a basement high, the San Marcos Arch,5 on the paleobathymetry of its depositional basin. The updip portions of the Chalk in the Austin and San Antonio regions are relatively shallow water deposits containing considerable quantities of benthic skeletal material. Deeper-water planktonic microfossils and nanofossils dominate the basin equivalents, although some benthic material was transported basinward in debris flows.5 Drake6 reports the updip portions of the chalk in Burleson County, Giddings field, to be less fractured than the downdip portions, with wells in the updip portions being poor producers. At McKinney Falls State Park, a pavement in the McKown formation is exposed where Onion Creek flows over the lower falls. The McKown formation is a lateral equivalent of the Austin Chalk and comprises chalk intercalated with pyroclastic deposits derived from Pilot Knob, a Cretaceous volcanic center 3 km to the southeast.7 The Grove Creek outcrop is stratigraphically at the top of the Upper Chalk, just below the overlying Ozan formation. The McKinney Falls outcrop is close to the overlying Taylor Marl. The horizontal Kinlaw core from Pearsall field is from the base of the lower Chalk in the Atco Member. Thus, stratigraphically and with respect to the basin architecture, the studied sites are disparate. It is not the intention of this paper to make definitive recommendations for drilling distance in the Austin Chalk based on so few sites, but rather to show with these examples how site-specific information may be used to this end. Data-Collection Methodology An important consideration in fracture studies is whether the fractures observed in a particular core or outcrop are representative of those fractures that occur in the subsurface and contribute to fluid flow. In the case of core studies, the main pitfalls surround the distinction of natural fractures from those induced by drilling or by the core-handling process. Kulander et al.8 provided a comprehensive guide to natural and induced fracture identification in cores, and their criteria were used here. In outcrop studies, the challenge is to distinguish those fractures that would have been formed in the subsurface, at an appropriate depth to be considered as a reservoir analog, from those fractures that developed during uplift and erosion. The fracture systems documented here are confined to those that exhibit partial or total mineral fill and that would have developed in the subsurface.

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