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A Petrophysical Method to Evaluate Irregularly Previous HitGasNext Hit Saturated Previous HitTightNext Hit Sands Which Have Variable Matrix Properties and Uncertain Water Salinities*

 

Michael Holmes1, Dominic Holmes1, and Antony Holmes1

 

Search and Discovery Article #40673 (2011)

Posted January 11, 2011

 

*Adapted from oral presentation at AAPG International Conference and Exhibition, Calgary, Alberta, Canada, September 12-15, 2010

 

1Digital Formation, Denver, Colorado ([email protected])

 

Abstract

 

A problem in many Rocky Mountain Previous HittightNext Hit Previous HitgasNext Hit sandstones is a sequence that is only partially Previous HitgasNext Hit saturated, with changing matrix properties combined with variable (and often unpredictable) water salinities. Often it is difficult to distinguish between high resistivity fresh water wet sands, and high resistivity, Previous HitgasNext Hit-bearing sands. A standard approach is to make a qualitative judgment based on density/neutron response – the Previous HitgasNext Hit “cross-over” effect. However, if matrix properties are variable, this approach can be misleading, and is at best a qualitative judgment.

 

The methodology presented here is a quantitative assessment of Previous HitgasNext Hit saturation by comparing matrix specific density and neutron responses with porosity, calculated such that Previous HitgasNext Hit effects are minimized. Cross plot porosity from density/neutron combination is only minimally affected by Previous HitgasNext Hit and by changing matrix properties.

 

Three sets of calculations are made assuming sandstone (bulk density 2.65 gm/cc), calcareous sandstone (bulk density 2.68 gm/cc) and heavily cemented calcareous sandstone, or limestone (bulk density 2.71 gm/cc). Quantified estimates of Previous HitgasNext Hit saturation, as “seen” by each log, are available for each assumed rock type. Pressure effects on porosity log responses are included in the calculations.

 

Four sets of saturation profiles are now available, one from standard resistivity log analysis and three from porosity log analysis assuming different matrix properties. Comparisons among the 4 sets of saturation profiles can be combined with other data, such as mud log shows and (if available) core measured matrix densities. Using such comparisons, it is often relatively simple to distinguish between wet intervals and Previous HitgasNext Hit-bearing intervals. With increasing assumed grain density, Previous HitgasNext Hit saturations calculated from the porosity logs increase. If Previous HitgasNext Hit saturations so defined are unrealistically high, it is an indication that actual grain density is less than assumed grain density.

 

Additionally, if matrix properties are well-defined, it is possible to verify Rw input for resistivity log interpretation, and adjust as necessary. It is important to recognize that the porosity logs, and particularly the density log, investigate close to the wellbore, and may well be influenced entirely by the flushed zone. Examples are presented from Rocky Mountain reservoirs, in sequences where the problem of irregular Previous HitgasNext Hit saturation in systems with variable Rw is particularly severe.

 

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Copyright � AAPG. Serial rights given by author. For all other rights contact author directly.

 

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fig01

Figure 1. Schematic of Previous HitgasNext Hit saturation from porosity log analysis (for shallow reservoirs).

fig02

Figure 2. Depth log from standard shaley formation resistivity analysis. Track descriptions are as follows: (1) raw wireline log; (2) reservoir composition, where yellow indicates matrix, red indicates porosity, and grey indicates shale; (3) water saturation, core data illustrated by blue and green symbols; (4) bulk volumes where grey indicates shale, brown indicates hydrocarbons, light blue indicates poor quality reservoir (possible mobile water), and dark blue indicates capillary bound water; (5) pay flags where yellow indicates gross reservoir, red indicates net reservoir, and green indicates net pay.

fig03

Figure 3. Interpretation of porosity vs. resistivity relations to determine parameters for Archie analysis. a (cementation constant) = 1.0, Rw (water resistivity) = 0.1, m (cementation exponent) = 2, and n (saturation exponent) = 1.7.

fig04

Figure 4. Depth log showing Previous HitgasNext Hit saturation from porosity log analysis. Track descriptions are as follows: (1) reservoir composition, where yellow indicates matrix, red indicates porosity, and grey indicates shale; (2) water saturation, core data illustrated by blue and green symbols; (3) bulk volumes, where grey indicates shale, brown indicates hydrocarbons, light blue indicates poor quality reservoir (possible mobile water), and dark blue indicates capillary bound water; (4) matrix properties - grain density and matrix travel time; (5) permeability, core data illustrated by black symbols. Tracks 6, 7, and 8 show porosity and Previous HitgasNext Hit saturation from porosity logs only. Yellow indicates Previous HitgasNext Hit saturation from porosity logs, and blue indicates water saturation from resistivity log analysis. Track 6 shows analysis assuming a grain density of 2.65 gm/cc, track 7 shows analysis assuming 2.68 gm/cc, and track 8 shows analysis assuming a grain density of 2.71 gm/cc. Track 9 contains pay flags where yellow indicates gross reservoir, red indicates net reservoir, and green indicates net pay. 9a shows pay flags from resistivity analysis, 9b shows pay flags from porosity log analysis assuming grain density of 2.65 gm/cc, 9c shows pay flags from porosity log analysis assuming grain density of 2.68 gm/cc, and 9d shows pay flags from porosity log analysis assuming grain density of 2.71 gm/cc.

 

Methodology

 

Shaley Formation Resistivity Analysis

 

The interpretation is a standard shaley formation analysis, involving calculations of total porosity, shale volume, and total water saturation. One of the issues in Previous HittightNext Hit Previous HitgasNext Hit sands is the correct choice of matrix lithology. If only a density log is used, the correct choice of grain density is crucial. In the event of lack of core data this may be particularly problematic, especially if grain density is variable. By using a density/neutron cross plot, this restriction is overcome. Fluid density is a required input, and should be estimated from a reasonable assumption of Previous HitgasNext Hit saturation close to the wellbore. A porosity/resistivity cross plot can help in this choice.

 

The second set of analysis involves the calculation of effective porosity and water saturation (i.e. removing the effects of clay). From these calculations, again based on resistivity interpretations, potential mobile water and/or poor quality reservoir rock can be distinguished from capillary bound water. Lack of light blue color fill on Figure 2, track 4 and Figure 4, track 3 equates to better quality, Previous HitgasNext Hit-bearing reservoirs. Example of application of these techniques are described in AAPG Annual Convention, June 2009 “Relationship Between Porosity and Water Saturation: Methodology to Distinguish Mobile from Capillary Bound Water ” by Michael Holmes, Antony Holmes, Dominic Holmes.

 

Previous HitGasNext Hit Saturation from Porosity Logs

 

Comparison of density with neutron logs is used routinely for a qualitative assessment of the presence of Previous HitgasNext Hit – the density/neutron “cross-over” effect. The response is controlled by the concentration of hydrogen in the pore space. Because Previous HitgasNext Hit contains less hydrogen than oil or water, apparent neutron porosity is suppressed. The cross plot (Figure 1) shows the effects of Previous HitgasNext Hit. Porosity values are lithology specific, i.e. raw logging data must be converted to a known (or presumed) lithology. By assuming different lithologies, the cross plot can be solved for Previous HitgasNext Hit saturation. The assumption is made that the density and neutron logs both investigate about the same volume of rock – or, as in the case of Previous HittightNext Hit Previous HitgasNext Hit sands, there is a little variation of Previous HitgasNext Hit saturation away from the wellbore (minimal or no invasion by drilling fluid). Three different lithologies are assumed in this paper:

 

 

 

Example

 

Standard resistivity interpretation from a Piceance Basin well, NW Colorado, is shown in Figure 2. Interpretation of the porosity resistivity cross plot (Figure 3) shows input used for saturation determination:

 

Rw = 0.1 Water resistivity

a = 1.0 Cementation constant

m = 2.0 Cementation exponent

n = 1.7 Saturation exponent

 

A summary of the interpretation is as follows:

  • Sands from 4850-5000 ft are either Previous HittightNext Hit (as at 4890-4910 ft) or wet (as at 4920-4940 ft).
  • From 5000-5140 ft the sands are routinely Previous HitgasNext Hit bearing and, for Previous HittightNext Hit sands, fair reservoir quality – average core permeability 0.1 mD or above.
  • From 5140-5200 ft, the sands are Previous HittightNext Hit – average core permeability less than 0.01 mD.

 

Figure 4 shows the same interval as Figure 2, with the addition of interpretations of Previous HitgasNext Hit saturation from porosity logs. Examination of the porosity log Sg data shows the following:

  • None of the sands has a grain density of 2.71 gm/cc (calculations assuming this value show unrealistically high Previous HitgasNext Hit saturations).
  • The shallower sands (above 5000 ft) appear to be mostly wet, with a grain density of 2.65 gm/cc - or they are Previous HitgasNext Hit bearing with a more saline water (lower Rw) than the shallower sands, with a grain density of 2.68. Core measured grain densities would help solve the problem.
  • Sands from 5000-5140 ft are Previous HitgasNext Hit bearing with a grain density of 2.68 gm/cc.
  • Sands below 5140 ft are not Previous HitgasTop bearing, regardless of assumed grain density.

 

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