Method and Apparatus for Measurement of Formation Fluid Loss

• US 20090260430A1
• Filed: 11/21/2008
• Published: 10/22/2009
• Est. Priority Date: 11/21/2007
• Status: Abandoned Application

• Current Assignee: Konstandinos Zamfes
• Original Assignee: Konstandinos Zamfes
• Inventors: Zamfes, Konstandinos
• Application Number:
  US12/275,388
• Publication Number:
  US 20090260430A1
• Time in Patent Office: Days
• US Class Current: 73/152.40
• CPC Class Codes: E21B 21/003 Means for stopping loss of drilling fluid plastering the borehole wall E21B33/138
• CPC Class Codes: E21B 21/08 Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure valve arrangements therefor E21B21/10
• CPC Class Codes: G01N 33/2823 Raw oil, drilling fluid or polyphasic mixtures

Abstract

A method for determining drilling fluid losses or gains by providing a drilling fluid, measuring a plurality of supply parameters of the drilling fluid, delivering the drilling fluid to a subsurface drilling operation, the subsurface drilling operation providing a returns drilling fluid, measuring a plurality of returns parameters of the returns drilling fluid, and determining change in composition, or loss of or gain of drilling fluid from a comparison between the supply parameters and the returns parameters.

Claims

1. A method for determining drilling fluid losses or gains in earth or rock drilling, comprising:

a. providing a drilling fluid to a drilling system for a drilling operation;

b. measuring a plurality of supply parameters of the drilling fluid;

c. delivering the drilling fluid to the subsurface drilling operation, the subsurface drilling operation providing a returns drilling fluid;

d. measuring a plurality of returns parameters of the returns drilling fluid; and

e. determining a change in drilling fluid composition, or loss of or gain of drilling fluid from a comparison between the supply parameters and the returns parameters.

2. The method of claim 1, further comprising:

f. recording a plurality of system conditions of the drilling system; and

g. correlating the system conditions and the supply parameters or the returns parameters.

3. The method of claim 1, wherein the supply parameters are selected from the group consisting of gamma ray, bulk density, temperature, velocity, heat conductivity, resistivity, and gas content.

4. The method of claim 1, wherein the returns parameters are selected from the group consisting of gamma ray, bulk density, temperature, velocity, heat conductivity, resistivity, cuttings, and gas content.

5. The method of claim 1, wherein the system conditions are selected from the group consisting of drilling rate of penetration, bit type, bit diameter, depth, rpm, cutting face depth, cuttings removed, additives added, mud pump pressure and mud pump flow output.

6. The method of claim 1, wherein the supply parameters are correlated to a depth of the subsurface drilling operation.

7. The method of claim 1, wherein the returns parameters are correlated to a depth of the subsurface drilling operation.

8. A method for determining the efficiency of a mud pump comprising:

a. providing a stroke, a displacement, and a speed for the mud pump to determine a theoretical flow rate;

b. measuring an actual flow rate;

c. comparing the actual flow rate and the theoretical flow rate.

9. The method of claim 8, wherein the actual flow rate is determined by velocity measurement.

10. A method for modeling a borehole shape in earth or rock drilling, comprising:

a. providing a drilling fluid to a drilling system for a subsurface drilling operation;

b. measuring a plurality of supply parameters of the drilling fluid;

c. delivering the drilling fluid to the subsurface drilling operation, the subsurface drilling operation providing a returns drilling fluid;

d. recording the depth of the drilling operation;

e. measuring a plurality of returns parameters of the returns drilling fluid; and

f. correlating the supply parameters, the return parameters, and depth to determining the borehole shape.

11. The method of claim 10, wherein an incremental section of borehole is modeled between a first depth and a second depth.

12. The method of claim 11, wherein a model diameter of the incremental section of the borehole is determined between the first depth and the second depth based upon a volume of the drilling fluid in the incremental section of the borehole.

13. The method of claim 12, wherein the volume of the drilling fluid in the incremental section of the borehole is determined from a volume of the drilling system, a volume of drilling fluid in the borehole above the first depth, a volume of drilling fluid in the drill pipe above the first depth, and a volume of the drilling fluid above ground.

14. The method of claim 12, wherein the model diameter is modeled in a plurality of incremental sections throughout the drilling of the borehole to provide the borehole shape.