Passive Imaging of Hydrofractures in the South Belridge Diatomite

Abstract

Summary We present the results of a seismic analysis of two hydrofractures spanning the entire diatomite column (1110-1910 ft or 338-582 m) in Shell's Phase II steam drive pilot in South Belridge, California. These hydrofractures were induced at two depths (1110-1460 and 1560-1910 ft) and imaged passively using the seismic energy released during fracturing. The arrivals of shear waves from the cracking rock ("microseismic events") were recorded at a 1 ms sampling rate by 56 geophones in three remote observation wells, resulting in 10GB of raw data. These arrival times were then inverted for the event locations, from which the hydrofracture geometry was inferred. A five-dimensional conjugate-gradient algorithm with a depth-dependent, but otherwise constant shear wave velocity model (CVM) was developed for the inversions. To validate CVM, we created a layered shear wave velocity model of the formation and used it to calculate synthetic arrival times from known locations chosen at various depths along the estimated fracture plane. These arrival times were then inverted with CVM and the calculated locations compared with the known ones, quantifying the systematic error associated with the assumption of constant shear wave velocity. We also performed Monte Carlo sensitivity analyses on the synthetic arrival times to account for all other, random errors that exist in field data. After determining the limitations of the inversion algorithm, we hand-picked the shear wave arrival times for both hydrofractures and inverted them with CVM. Finally, to correct for the areal inhomogeneity of the rock, we calculated the distortion of conical waves that were generated by air gun blasts in a remote observation well. This novel technique improved significantly the accuracy of the event locations in the shallow hydrofracture. The azimuth of both hydrofractures was N21 4 E. In each treatment well, there were two separate hydrofractures at two different depths that correspond to the diatomite layers with higher permeabilities. Both shallow hydrofractures were asymmetrical. Initially, the upper, NE wing was 230 ft long, whereas the lower SW wing was only 30 ft long. The deep hydrofracture was symmetrical and the wings of its two parts were initially 130 and 10 ft long, respectively. These conclusions agree well with temperature surveys in the surrounding observation wells during steam injection. Introduction The late and middle Miocene diatomaceous oil fields in the San Joaquin Valley, California, are located in Kern County, some forty miles west of Bakersfield. The largest oil volumes are found in the South, Middle and North Belridge Diatomite and Brown Shale, Lost Hills Diatomite and Brown Shale, Antelope Hills, McDonald Anticline, Chico-Martinez Chert, Cymric Diatomite, McKittrick, Railroad Gap, Belgian Anticline, Asphalto, Elk Hills, Buena Vista Antelope Shale, and Midway Sunset Reef Ridge and Antelope Shale. The major producers of diatomite oil are Shell, Mobil, Chevron, Santa Fe, Crutcher Tufts, Exxon, Texaco, and Unocal. An estimated original-oil-in-place in the Monterey diatomaceous fields exceeds 10 billion barrels and is comparable to that in Prudoe Bay in Alaska.

Heavy and Thermal Oil Recovery Production Mechanisms, SUPRI TR-127

“…With more fields approaching maturity and abandonment, recovery options are required for more difficult to produce reservoirs such as low permeability diatomite and chalk formations. For example, estimates place the amount of original oil (OOIP) in the diatomaceous and siliceous shale formations of California at 12 to 18 billion bbl (Ilderton et al, 1996). Although the volumes of oil in place are large, the low permeability creates challenging issues in producing this oil.…”

Modeling Permeability Alteration in Diatomite Reservoirs During Steam Drive, SUPRI TR-113

“…Collectively, they contain an estimated 10 billion barrels of original oil in place (OOD?) (Ilderton et al, 1996). The diatomaceous formations in these areas are thick, highly layered, and relatively shallow (1000-2000 ft.).…”

Hydrofracture Properties via Signals from Hydraulic Pumps, an Overview

“…thick. Vertical ellipsoid with two symmetric wings transmitting without end from the wellbore arranged opposite to the direction of slightest primary anxiety (Ilderton et al, 1996). The coveted arm compass of every crack is regularly around 300 ft tip-to-tip, and the sought stature speaks the truth 100-150 ft. Wells are thickly separated every 165 ft or less., making the learning of hydraulic break geometry orientation, length, stature, symmetry and profundity fundamental in deciding ideal right areas (Lacy, 1987).…”