A Comprehensive Study of
b-Values for Proven Reserve Estimation Using Hyperbolic Decline for Vertical Commingled Gas Producers in Deep Basin Area of WCSB
- Shaoyong Yu (ConocoPhillips Canada Ltd.)
- Document ID
- Society of Petroleum Engineers
- SPE/CSUR Unconventional Resources Conference, 20-22 October, Calgary, Alberta, Canada
- Publication Date
- Document Type
- Conference Paper
- 2015. Society of Petroleum Engineers
- 5.7 Reserves Evaluation, 5.8 Unconventional and Complex Reservoirs, 5.8.1 Tight Gas, 5 Reservoir Desciption & Dynamics, 4.6 Natural Gas, 5.5 Reservoir Simulation, 1.6 Drilling Operations, 4.6 Natural Gas
- Proven Reserve Estimation for Commingled Wells, Vertical Commingled Gas Producers in Deep Basin Ar, Study of b-Values
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Since its discovery in the 1970's, more than 30,000 dry gas wells (over 90% of them vertical producers) have been drilled within the Deep Basin area of the Western Canada Sedimentary Basin (WCSB). Typically these wells produce from tight to medium-tight formations such as the Paddy, Cadotte, Notikewin, Falher-A, Falher-B, Falher-C, Bluesky, Cadomin and Nikanassin. The permeability of these formations ranges from about 0.001mD to 1.0mD.
In an effort to maximize value, over half of the vertical wells within the Deep Basin have been commingled, producing gas from multiple formations. Every year, reservoir engineers evaluate the Proven (PDP) and/or Proven plus Probable (2P) reserves of these wells using Arps' traditional Decline Curve Analysis (DCA). In regards to hyperbolic declines, many questions frequently arise concerning the choice of b-values. Specifically, some those questions are:
What b-value should be selected for wells producing from multiple formations with similar permeabilities?
What b-value should be selected for wells producing from multiple formations with differing permeabilities?
What is the impact on b-values if the producing layers have different pressure gradients?
What is the impact on b-values if the producing layers have different drainage areas?
What is the impact on b-values if the producing layers are completed differently?
In the early 90's, Fetkovich had conducted an extensive study on b-values for conventional reservoirs to answer the aforementioned questions. In his study, however, the reservoir permeability that was investigated ranged from 1mD to 1000mD. This paper will discuss a comprehensive study extending Fetkovich's work to much tighter reservoirs with permeability ranging from 0.001mD to 0.1mD. This study has been conducted by simulating the annual reserve review process (using hyperbolic declines to match synthetic data from a commercial reservoir simulator) and has been further validated through practical well examples.
Most importantly, a new formula has been developed to derive b-values for hyperbolic declines. This formula is especially applicable to tight gas reservoirs and will assist in answering the aforementioned questions.
|File Size||3 MB||Number of Pages||20|
Rushing, J. A., Perego, A. D., Sullivan, R. B., and Blasingame, T. A.: "Estimating Reserves in Tight Gas Sands at HP/HT Reservoir Conditions: Use and Misuse of an Arps Decline Curve Methodology," paper SPE 109625 presented at the 2007 Annual SPE Technical Conference and Exhibition, Anaheim, CA, 11-14 November 2007.