Flooding analysis tool and method thereof

Patent metadata

Field	Value
Publication number	US-2016177690-A1
Application number	US-201514832826-A
Country	US
Kind code	A1
Filing date	Aug 21, 2015
Priority date	Aug 22, 2014
Publication date	Jun 23, 2016
Grant date	—

Abstract

Described herein are various embodiments of computer-implemented methods, computing systems, and program products for analyzing a flood operation on a hydrocarbon reservoir. For example, an embodiment of a computer implemented method of analyzing at least a first flood operation and a second flood operation. The embodiment includes, for each flood operation: receiving production data and injection data, running capacitance resistance modeling, using the generated response times, the generated interwell connectivities, the received production data, the received injection data, or any combination thereof to generate a proxy of pore volume swept per well pair, and aggregating the generated proxies to generate an estimate of pore volume swept at a well level, at a reservoir level, or both for the flood operation. The embodiment also includes comparing the generated estimate of pore volume swept to determine a change in sweep efficiency at the well level, at the reservoir level, or both.

First claim

What is claimed is:

1 . A computer implemented method of analyzing at least a first flood operation and a second flood operation on a hydrocarbon reservoir having at least one production well and at least one injection well, the method comprising:
for each of the first flood operation and the second flood operation:
receiving production data for the at least one production well and injection data for the at least one injection well for the flood operation;
running capacitance resistance modeling using the received production data and the received injection data for the flood operation to generate a response time and an interwell connectivity per injection well and production well pair for the flood operation;
using the generated response times, the generated interwell connectivities, the received production data, the received injection data, or any combination thereof to generate a proxy of pore volume swept per injection well and production well pair for the flood operation; and
aggregating the generated proxies of pore volume swept per injection well and production well pair for the flood operation to generate an estimate of pore volume swept at a well level, at a reservoir level, or both for the flood operation; and
comparing the generated estimate of pore volume swept for the first flood operation and the generated estimate of pore volume swept for the second flood operation to determine a change in sweep efficiency at the well level, at the reservoir level, or both.

2 . The method of claim 1 , further comprising, for each of the first flood operation and the second flood operation, determining heterogeneity at the well level, the reservoir level, or both.

3 . The method of claim 2 , further comprising comparing the determined heterogeneity of the first flood operation and the determined heterogeneity of the second flood operation to determine a change in heterogeneity at the well level, at the reservoir level, or both.

4 . The method of claim 3 , further comprising comparing the determined change in heterogeneity and the determined change in sweep efficiency to verify accuracy of the determined change in sweep efficiency.

5 . The method of claim 1 , wherein the hydrocarbon reservoir includes a plurality of zones, and wherein each zone is treated as an injection well.

6 . The method of claim 1 , wherein the production data includes production rate and flowing pressure data as a function of time, and wherein the injection data includes injection rate and flowing pressure data as a function of time.

7 . The method of claim 1 , wherein the first flood operation, the second flood operation, or both is a polymer flood operation, further comprising accounting for rheology of the polymer used in the polymer flood operation in the running of the capacitance resistance modeling.

8 . The method of claim 7 , wherein accounting for the rheology in running capacitance resistance modeling includes separating each injection well and production well pair of the polymer flood operation into at least three tanks, wherein the three tanks include a near injection well tank, a near production well tank, and a middle tank between the near injection well tank and the near production well tank.

9 . The method of claim 8 , wherein the production data includes production rate and flowing pressure data as a function of time, and wherein the injection data includes injection rate and flowing pressure data as a function of time, and wherein accounting for the rheology in running capacitance resistance modeling includes using (i) material balance equations for each of the tanks, (ii) the injection and production rates, (iii) the injection and production flowing pressure data, and (iv) a polymer rheology.

10 . The method of claim 8 , wherein accounting for the rheology in running capacitance resistance modeling includes using a capacitance resistance modeling polymer formulation:

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Assignees

• Chevron Usa Inc

Inventors

• Sayarpour Morteza
• Fathi Najafabadi Nariman
• Jain Lokendra

Classifications

• E21B43/16

  Enhanced recovery methods for obtaining hydrocarbons · CPC title

• E21B43/14

  Obtaining from a multiple-zone well · CPC title

• E21B49/00

  Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells · CPC title

• G01N27/22

  by investigating capacitance · CPC title

• E21B43/20 Primary

  Displacing by water · CPC title