NMR sequential fluid characterization
Methods and systems for determining location of hydrocarbon in unconventional plays are provided. The methods provide at least two steps of measuring formation samples as received, as dried and/or as saturated using high resolution NMR, and subsequent processing of the NMR data to determine one of several formation properties or components where the formation property or the component can be used to locate an oil or gas reservoir, complete a well, and/or increase production efficiency. Also, the present methods provide a series of sequential and ordered combination of steps related to the financial evaluation of number of barrels of oil or cubic feet of gas which can be produced at a location.
1. A method for determining location of hydrocarbon in unconventional plays:
comprising the steps of:
(a) receiving a sample from a reservoir;
(b) performing an NMR measurement on the formation sample to acquire a first NMR data set;
(c) drying the sample to form a dried sample;
(d) performing an NMR measurement on the dried sample to acquire a second NMR data set:
(e) saturating the dried sample with a fluid to form a saturated sample;
(f) performing an NMR measurement on the saturated sample to acquire a third NMR data set; and
(g) analyzing the first NMR data set, the second NMR data set and the third NMR data set to obtain at least one formation property or one component, wherein the formation property or the component is used to locate an oil or gas reservoir or well, and/or complete the well.
2. The method of claim 1 , wherein the formation property or component is selected from the group consisting of total porosity, moveable fluid porosity, capillary bound fluid porosity, clay bound fluid porosity, residual hydrocarbon, and heavy hydrocarbon.
3. The method of claim 1 , wherein the fluid is brine.
4. The method of claim 1 , wherein the sample is dried for at least a day.
5. The method of claim 1 , wherein the first NMR data set is an as received sample matrix, the second NMR data set is a dry sample matrix, and the “as received” sample matrix minus the “dry” sample matrix represents one or more of the following: capillary bound fluid, clay bound water, residual hydrocarbon and/or capillary bound porosity.
6. The method of claim 5 , wherein the third NMR data set is a saturation sample matrix and the saturation sample matrix minus the dry sample matrix quantifies mobile hydrocarbon.
7. A method of sequential fluid characterization comprising the steps of:
obtaining a sample from a reservoir;
acquiring a first set of high resolution NMR data on the sample;
drying the sample to produce dried sample;
acquiring a second set of high resolution NMR data on the dried sample;
determining residual hydrocarbon, heavy hydrocarbon and capillary bound porosity based on the first and the second sets of NMR data; and
commencing oil and/or gas production based on the determination of the heavy hydrocarbon and/or the residual hydrocarbon.
8. A method of sequential fluid characterization comprising the steps of:
obtaining a sample from a reservoir;
drying the sample to produce dried sample;
acquiring a first set of high resolution NMR data on the dried sample;
saturating the sample with a fluid;
acquiring a second set of high resolution NMR data on the saturated sample; and
determining movable porosity based on the first and the second sets of NMR data; and
commencing oil or gas production based on the determination of a heavy hydrocarbon and/or a residual hydrocarbon.
9. A method of sequential fluid characterization comprising the steps of:
obtaining a sample from a reservoir;
acquiring a first set of high resolution NMR data on the sample;
drying the sample to produce dried sample;
acquiring a second set of high resolution NMR data on the dried sample;
determining movable porosity based on the first and the second sets of NMR data; and
commencing oil or gas production based on the determination of a heavy hydrocarbon and/or a residual hydrocarbon.