--> Comprehensive Use of VSP Technology at Elk Hills Field, Kern County, California, by R.J. Brewer and Don Greenfield, #40091 (2003).
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Comprehensive Use of Previous HitVSPNext Hit Technology at Elk Hills Field, Kern County, California*

By

R.J. Brewer1 and Don Greenfield2

 Search and Discovery Article #40091 (2003) 

 

*The viewer is referred to two other articles about Previous HitVSPNext Hit, written by the senior author, The Look Ahead Previous HitVSPNext Hit Survey: Its Utility and Future, Search and Discovery Article #40060 (2002) and Previous HitVSPNext Hit Previous HitDataNext Hit in Comparison to the Check Shot Velocity Survey, Search and Discovery Article #40059 (2002).  

1Halliburton Energy Services, Houston, TX ([email protected]).

2Occidental of Elk Hills, Inc. 

 

Introduction 

To understand accurately subsurface rock formation and pay zone seismic travel times and velocities within the historic Elk Hills oil field in Kern County, San Joaquin Valley, California (Figure 1), Occidental of Elk Hills, Inc. in 1999 embarked on one of the first coordinated and comprehensive Previous HitVSPNext Hit survey Previous HitdataNext Hit acquisition programs in the country. The trend-setting effort, uncommon in the United States, has helped produce more accurate surface seismic time-to-drill depth conversions. This result has been more accurate drilling prospect maps. Previous HitVSPNext Hit Previous HitdataNext Hit has proven to be an effective means to lower drilling ambiguities as well as overall drilling costs in the Elk Hills field. It was concluded that rigorous integration of the all the Previous HitVSPNext Hit Previous HitdataNext Hit recorded during the campaign into a entire surface and borehole seismic Previous HitdataNext Hit set significantly improved the accuracy of a complex subsurface structural mapping process. Knowledge of the challenging stratigraphy of the area has also been enhanced. The result has been markedly improved  success rates for exploration and development well drilling.  

Occidental purchased the Elk Hills field from the United States government in late 1998. As part of a comprehensive plan to assist development drilling and to prepare for exploration drilling, Oxy acquired an 80 square mile seismic survey and completed preliminary mapping throughout the Elk Hills field. Previous 2D and limited Previous Hit3DNext Hit seismic acquisition had proved problematic at best, yielding poor Previous HitdataNext Hit. Near surface low velocity air sands and extreme topographic variability (Figure 2) hampered surface seismic Previous HitdataNext Hit quality. Careful pre-3D acquisition testing and extensive quality control yielded a Previous Hit3DNext Hit seismic volume that was magnitudes better than any previous acquisition efforts (Figures 3 and 4).  

It has long been known that Previous HitVSPNext Hit Previous HitdataNext Hit has the established advantage of being generally higher frequency and better quality than surface seismic. The Previous HitVSPNext Hit’s one-way travel path from energy source to receiver helps prevent dissipation of frequency and amplitude. Consequently, following the Previous Hit3DNext Hit seismic acquisition, a comprehensive wellbore velocity Previous HitdataNext Hit acquisition program was initiated. Although there were nearly 5,000 wells within the Elk Hills field, prior to the checkshot/Previous HitVSPNext Hit acquisition program, there were only 11 checkshots within the Elk Hills Field and another 6 checkshots surrounding the field (Figure 5). During the 1980's, one or two VSPs had been acquired. However, no digital Previous HitVSPNext Hit records were extant; and only checkshot Previous HitdataNext Hit remained.

 

 

uIntroduction

uFigure captions

uAquisition of Previous HitdataNext Hit

uMethodology

uResults

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

uIntroduction

uFigure captions

uAquisition of Previous HitdataNext Hit

uMethodology

uResults

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

uIntroduction

uFigure captions

uAquisition of Previous HitdataNext Hit

uMethodology

uResults

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

uIntroduction

uFigure captions

uAquisition of Previous HitdataNext Hit

uMethodology

uResults

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

uIntroduction

uFigure captions

uAquisition of Previous HitdataNext Hit

uMethodology

uResults

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

uIntroduction

uFigure captions

uAquisition of Previous HitdataNext Hit

uMethodology

uResults

 

 

Figure Captions

Figure 1:  Location map of Elk Hills Field, Kern County, San Joaquin Valley, California.

Figure 2:  Digital terrain model showing extreme topographic variations. Yellow and red denotes higher elevations and blue lower elevations.

 

Figure 3:  Elk Hills Oil Field highlighting the locations of major structural features, well control, and comparative seismic Previous HitdataNext Hit.

 

Figure 4:  Comparison of high effort, high quality 2D seismic Previous HitdataNext Hit versus the high effort Previous Hit3DNext Hit seismic Previous HitdataNext Hit.

 

Figure 5:  Velocity Previous HitdataNext Hit prior to Previous HitVSPNext Hit/Checkshot acquisition program: 11 checkshots in the field and 5 checkshots around the field. Several VSPs had previously been acquired; but there were no digital Previous HitdataNext Hit, and paper records were poor.

 

Figure 6:  Velocity Previous HitdataNext Hit after acquisition program:  seven new check shot velocity surveys and 36 new VSPs.

 

 

Click to view sequence of Figures 5 and 6 for comparison of velocity Previous HitdataNext Hit prior and after acquisition program.

 

Figure 7:  VSP/3D seismic Previous HitdataNext Hit correlation. Previous HitVSPNext Hit Previous HitdataNext Hit was convolved with an extracted wavelet from the Previous Hit3DNext Hit seismic and incorporated into the Previous Hit3DNext Hit dataset to facilitate well tie formation correlations.

 

Figure 8:  Elk Hills south flank location, 351-17G.

 

 

Figure 9:  Seismic backdrop cross section through the 351-17G well.

 

 

Figure 10:  Comparison of pre-drill velocity function (KNRVP generated from substantial checkshot/Previous HitVSPNext Hit Previous HitdataNext Hit) with actual velocity function from Previous HitVSPNext Hit Previous HitdataNext Hit shot in 351-17G well.

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Acquisition of Previous HitVSPNext Hit Previous HitDataNext Hit 

The original acquisition plan called for at least one velocity point for each square mile. As the benefits of velocity Previous HitdataNext Hit became apparent, the effort was increased. Velocity points exceeded one per square mile in many drilled areas of the field. The first phase of the project included both checkshots and VSPs while subsequent phases recorded virtually all VSPs. 

Zero offset Previous HitVSPNext Hit surveys utilizing a vibroseis energy source located as close as possible to the wellhead were acquired in selected, recently-drilled development wells as well as in key existing wells slated for workover. Of course, preference was given to deeper wells. VSPs were recorded in every exploration well. Acquisition was performed in open hole wells, cased hole wells, and both combination open/cased hole wells. Close coordination and cooperation between exploitation/exploration, drilling, field operations, and the contractor were essential for the ultimate success in the acquisition effort. Figure 6 shows the density and locations of checkshot and Previous HitVSPNext Hit surveys in the field area after implementation of the borehole seismic survey program. Acquisition through January 2003 provided seven new check shot velocity surveys and 36 new VSPs. 

While zero offset VSPs were the goal, many times vibrators had to be offset in order to suppress noise attributable to ground roll and "ringing" pipe. Every effort was made to keep offsets less than 500 feet. However, due to excessive noise and topographic problems, one Previous HitVSPNext Hit was acquired with a 1,000-foot offset. Although this offset was considered excessive, the survey was acquired to test the viability of the Previous HitdataNext Hit. The resultant Previous HitdataNext Hit were excellent. 

Whenever possible, 50-foot level intervals were acquired with a dual station downhole geophone tool assembly from TD to near surface. These 50-foot intervals were chosen after careful modeling indicated that this spacing would be sufficient to correlate with Previous Hit3DNext Hit surface seismic and avoid aliasing. Dual tool deployment helped save as much as 40% rig time over a single tool operation. Well depths typically ranged from 6,000 to 12,000 feet. Gamma ray acquisition combined with strip log correlation was run on most surveys to tie the velocity Previous HitdataNext Hit with original well log suites, especially where a drilling rig was absent and a mast truck was utilized. Slim (1-11/16-in.OD) downhole geophone tools were used on some surveys where borehole conditions and equipment prevented utilization of the regular tools. Pressure control equipment was used on several occasions.  

In-field Previous HitdataNext Hit processing, to produce a corridor stack from the field records, was employed on virtually every survey to give quick-look verification of Previous HitdataNext Hit quality at the wellsite and to expedite overall Previous HitdataNext Hit integration and interpretation. On numerous wells, the in-field corridor stacks and Previous Hit3DNext Hit seismic Previous HitdataNext Hit ties were enhanced by convolving the corridor Previous HitdataNext Hit with a wavelet extracted from the Previous Hit3DNext Hit surface seismic. The digital wavelet Previous HitdataNext Hit were provided to the logging engineer so that field comparisons could be performed immediately. Previous HitVSPNext Hit and seismic Previous HitdataNext Hit correlation quality varied throughout the field but was generally very good. Further high-end Previous HitVSPNext Hit processing techniques have been used to enhance the correlation quality significantly. Figure 7 shows one of the excellent VSP-3D seismic ties in the eastern portion of the field. 

At the beginning, postulated expenditures for the aggressive acquisition project were a concern. Monetary concerns were mitigated and cost reductions were made possible by competitive bidding along with an Oxy/contractor agreement that guaranteed an average number of VSPs per month in return for significant cost breaks. This agreement has thus far saved Oxy approximately 40% to 50% over individually contracted VSPs.

 

Methodology 

A significant part of the exploration and development methodology employed by Oxy involves being able to produce accurate time-depth functions at any X-Y location encompassed by the surface seismic Previous Hit3DNext Hit and a time-depth function and/or Previous HitsyntheticNext Hit seismogram for every well in the field. This criterion is made possible by the integration of the numerous checkshot and Previous HitVSPNext Hit surveys recorded throughout the Elk Hills field and surrounding area. The Previous HitdataNext Hit integration and transformation to a Previous Hit3DNext Hit velocity volume was accomplished by using the Keystone Natural Resources Velocity Project (KNRVP) software suite. KNRVP allows nearly instantaneous creation and update of a Previous Hit3DNext Hit velocity volume by incorporating all checkshot, Previous HitVSPNext Hit, and 2D/3D seismic velocity information (such as stacking or RMS velocities). KNRVP provides unique time-to-depth functions  for any XY location within the boundaries of the velocity volume and thereby produces a unique time-depth function for every well. At Elk Hills, this capability means immediate updating of the velocity functions for the field's nearly 5,000 wells. The database feeding the computer aided exploration interpretation software can be updated immediately using the software output. Exact well log correlations with the Previous Hit3DNext Hit seismic can then be carried out. Final incremental well shifts involving synthetics and stretching/squeezing of the well Previous HitdataNext Hit to fit the Previous Hit3DNext Hit seismic Previous HitdataNext Hit are used to create a very detailed and accurate Previous Hit3DNext Hit velocity volume that matches seismic interpretation and well picks exactly. KNRVP has built-in functionality to avoid "impossible" velocity inversions that hamper other software packages when dealing with many Previous HitdataNext Hit points and/or very closely spaced Previous HitdataNext Hit points.

 

Results 

Utilizing a cost effective and aggressive velocity acquisition program along with innovative analysis has enabled interpreters to incorporate all geophysical and geological Previous HitdataNext Hit into a comprehensive picture and to predict accurately drill depths to targeted horizons. A good example of this predictive capability is the 351-17G well. The 351-17G deep test well was drilled on the south side of the Elk Hills field and was programmed to test a previously undrilled subthrust fault block. Figure 8 shows the location of the 351-17G well with respect to Elk Hills. Figure 9 is a seismic backdrop cross section including the final drilled well. A predicted velocity function was derived from the KNRVP velocity volume created with the substantial checkshot and Previous HitVSPNext Hit Previous HitdataNext Hit previously acquired. Figure 10 compares the pre-drill software velocity function with the post-drill velocity function from the Previous HitVSPNext Hit. The pre-drill predicted velocity function is remarkably close to the true velocity function defined by the Previous HitVSPNext Hit. 

Some practitioners have reportedly recommended that ideally one Previous HitVSPNext Hit survey be acquired for each 1-2 square miles of Previous Hit3DTop surface seismic coverage. The Occidental of Elk Hills project has demonstrated that the recommendation is a good one. The elimination of drilling ambiguities is important to the optimization of a multi-well exploitation drilling program.

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