Method for predicting hydrate formation

Patent metadata

Field	Value
Publication number	US-9828847-B2
Application number	US-201515317119-A
Country	US
Kind code	B2
Filing date	May 21, 2015
Priority date	Jun 10, 2014
Publication date	Nov 28, 2017
Grant date	Nov 28, 2017

Abstract

A method for predicting a formation of hydrates in a wellbore/riser annulus during a drilling operation. The method includes logging actual mud properties. Actual sets of pressure and temperature data at given locations/intervals in the wellbore or in the drilling riser annulus are continuously measured and/or calculated. A theoretical temperature profile for the formation of hydrates dependent on mud properties and pressure as a function of a true vertical depth in a well is determined. The theoretical temperature profile for the formation of hydrates in a control system is stored. The measured and/or calculated actual sets of pressure and temperature data is compared with the theoretical temperature profile for the formation of hydrates. A signal is issued if the measured and/or calculated actual sets of pressure and temperature data falls below or is lower than a predefined safety margin for the theoretical temperature profile for the formation of hydrates.

First claim

What is claimed is:

1. A method for predicting a formation of hydrates in a wellbore or in a drilling riser annulus if a gas is present, the method comprising:
pumping mud into the wellbore;
logging actual mud properties;
continuously measuring and/or calculating actual sets of pressure data and temperature data at given locations/intervals in the wellbore or in the drilling riser annulus;
determining a theoretical temperature profile for the formation of hydrates dependent on mud properties and pressure as a function of a true vertical depth in a well;
storing the theoretical temperature profile for the formation of hydrates in a control system;
comparing the measured and/or calculated actual sets of pressure data and temperature data with the theoretical temperature profile for the formation of hydrates; and
issuing a signal from a control system if the measured and/or calculated actual sets of pressure data and temperature data falls below or is lower than a predefined safety margin for the theoretical temperature profile for the formation of hydrates,
wherein,
the method is performed while drilling.

2. The method as recited in claim 1 , wherein the continuously measuring and/or calculating the actual sets of pressure data and temperature data is preformed via at least one first pressure transmitter and at least one first temperature transmitter arranged in a first position in the well, and at least one second pressure transmitter.

3. The method as recited in claim 2 , wherein the at least one first temperature transmitter and the at least one first pressure transmitter are arranged in an open hole section of the well.

4. The method as recited in claim 2 , wherein the continuously measuring and/or calculating the actual sets of pressure data and temperature data is preformed via a plurality of pressure transmitters arranged in a fixed vertical distance in the well, and
the method further comprises measuring and/or calculating a temperature at different locations in the well.

5. The method as recited in claim 1 , further comprising:
displacing a drilling riser if the temperature in the drilling riser is below the theoretical temperature profile for the formation of hydrates;
pumping fresh mud down at least one booster line so as to circulate out gas cut mud;
monitoring a possible rapid gas expansion as the hydrates melt at a low pressure; and
preparing to divert overboard so as to avoid a drilling riser blow-out on a drill floor.

6. The method as recited in claim 1 , further comprising, in case a wellbore influx has inadvertently passed a subsea blowout preventer:
pumping mud down at least one booster line so as to circulate out gas cut mud;
monitoring a possible rapid gas expansion; and
preparing to divert overboard so as to avoid a drilling riser blow-out on a drill floor.

7. The method as recited in claim 1 , further comprising:
filling at least one kill line with a hydrate inhibitor fluid;
injecting the hydrate inhibitor fluid present in the at least one kill line in a blow out preventer; and, simultaneously therewith,
pumping mud down a drill string so as to circulate out wellbore fluids, to inhibitor up at least one choke line, and to divert to a mud gas separator.

8. The method as recited in claim 1 , further comprising:
determining whether a choke line shut-in pressure shows an abnormal pressure decrease; and, if an abnormal pressure decrease is determined,
generating a wellbore influx and a hydrate alarm.

9. The method as recited in claim 1 , further comprising:
observing an increased drag trend or torque oscillation during connections and/or an abnormal pressure increase or pressure oscillation during a circulation so as to identify a stuck pipe situation as a possible result of hydrate formation; and
confirming the fulfillment of each of the following conditions:
drilling in a permeable formation which has been identified to have an ability to act as a reservoir rock as well as having a pressure close to or higher than a bottom hole pressure or a measured pressure at a pressure transmitter in the well,
observing that the temperature in the wellbore is below a hydrate formation temperature, and
observing a circulation restriction or a pressure peak.

10. The method as recited in claim 9 , wherein, in case of the stuck pipe situation caused by hydrate formation, the method further comprises:
injecting hydrate inhibitor fluid close to a wellhead,
stopping a circulation so as to allow a temperature in a formation to increase a temperature of fluids in the well so as to perform a hydrate dissociation process comprising melting or dissociating the hydrates into water and dense gas;
performing a flow check to verify that the hydrate dissociation process has started;
shutting-in the well if the well starts to flow; and
monitoring a shut-in pressure increase to determine a size of a hydrate plug/kick.

11. A method for predicting a formation of hydrates in a wellbore or in a riser annulus if a gas is present, the method comprising:
logging actual mud properties;
continuously measuring and/or calculating actual sets of pressure data and temperature data at given locations/intervals in the wellbore or in the riser annulus;
determining a theoretical temperature profile for the formation of hydrates dependent on mud properties and pressure as a function of a true vertical depth in a well;
storing the theoretical temperature profile for the formation of hydrates in a control system;
comparing the measured and/or calculated actual sets of pressure data and temperature data with the theoretical temperature profile for the formation of hydrates;
issuing a signal from a control system if the measured and/or calculated actual sets of pressure data and temperature data falls below or is lower than a predefined safety margin for the theoretical temperature profile for the formation of hydrates;
observing an increased drag trend or torque oscillation during connections and/or an abnormal pressure increase or pressure oscillation during a circulation so as to identify a stuck pipe situation as a possible result of hydrate formation; and
confirming the fulfillment of each of the following conditions:
drilling in a permeable formation which has been identified to have an ability to act as a reservoir rock as well as having a pressure close to or higher than a bottom hole pressure or a measured pressure at a pressure transmitter in the well,
observing that the temperature in the wellbore is below a hydrate formation temperature, and
observing a circulation restriction or a pressure peak.

12. The method as recited in claim 11 , wherein, in case of the stuck pipe situation caused by hydrate formation, the method further comprises:
injecting hydrate inhibitor fluid close to a wellhead,
stopping a circulation so as to allow a temperature in a formation to increase a temperature of fluids in the well so as to perform a hydrate dissociation process comprising melting or dissociating the hydrates into water and dense gas;
performing a flow check to verify that the hydrate dissociation process has started;
shutting-in the well if the well starts to flow; and
monitoring a shut-in pressure increase to determine a size of a hydrate plug/kick.

Assignees

• Mhwirth As

Inventors

• Vavik Dag

Classifications

• E21B43/00

  Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells (applicable only to water E03B) · CPC title

• E21B44/00 Primary

  Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions · CPC title

• E21B41/0007 Primary

  for underwater installations (E21B41/005, E21B41/04, E21B41/06, E21B41/08, E21B41/10 take precedence) · CPC title

• G01V9/005

  by thermal methods, e.g. after generation of heat by chemical reactions · CPC title

• E21B47/06

  Measuring temperature or pressure · CPC title