Abstract
The pressure of a reservoir is the key driving force for the primary recovery of hydrocarbon. It gives an indication of the amount of hydrocarbon remaining in the reservoir at any given time. Three types of pressure regime is encountered during the drilling process; which are the normal, abnormal and the subnormal pressure. During production of the hydrocarbon, as soon as the well is open to flow, the reservoir pressure starts declining, depending on the drive mechanism of the reservoir and at any point in time, the average value of pressure is estimated. In this chapter, solved example questions on determination of fluid contacts from pressure survey data and averaging of reservoir pressures are presented. In addition, the position of the reservoir fluid contact is not static as the fluid is produced. At first, the position of the fluid contacts are first determined within control wells and then extrapolated to other parts of the field. Once initial fluid contact elevations in control wells are determined, the contacts in other parts of the reservoir can be estimated. Hence, the various methods of estimating reservoir fluid contact are presented with solved example questions.
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References
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Exercises
Exercises
- Ex 8.1:
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An exploratory well penetrates a reservoir near the top of the oil column. Logs run in the well clearly located the gas-oil contact at 5200Â ft also DST test conducted on this well and sample analysis of the fluid sample collected from the same well gave reservoir pressure of 2402 psia at 5250Â ft and oil gradient of 0.35Â psi/ft the depth of the oil-water contact is uncertain because it could not be confirmed by logs.
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Determine the probable oil-water contact
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What is the pressure at the crest of the reservoir?
- Ex 8.2:
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Calculate the average reservoir pressure at the Datum depth of 8750 ftss for the following fluid pressure gradients, given that the GOC and OWC are at 8700 ftss and 8800 ftss respectively:
Well AÂ =Â 3685 psig at 8690 ftss |
Well BÂ =Â 3716 psig at 8800 ftss |
Well CÂ =Â 3725 psig at 8820 ftss |
Well DÂ =Â 3689 psig at 8710 ftss |
Well EÂ =Â 3713 psig at 8790 ftss |
- Ex 8.3:
-
A well penetrates a reservoir near the top of a fluid column. The GOC has been detected by logs but the OWC. An oil sample was taken at 7890Â ft TVD with a pore pressure of 3080 psig recorded. The field water gradient is 0.445Â psi/ft, oil gradient is 0.347Â psi/ft find the OWC.
- Ex 8.4:
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The result of an RFT tests conducted on an appraisal well in a field located in the Niger Delta region is presented in the table below. Determine the types of hydrocarbons present and find the fluid contact.
Depth TVD (ft) | Formation Pressure (psia) |
---|---|
11,200 | 4648 |
11,300 | 4656 |
11,450 | 4664 |
11,500 | 4672 |
11,600 | 4730 |
11,700 | 4745 |
11,820 | 4778 |
11,900 | 4810 |
- Ex 8.5:
-
The result of an RFT tests conducted on an appraisal well in a field located in the Niger Delta region is presented in the table below. Determine the types of hydrocarbons present and find the fluid contacts
Depth TVD (ft) | Formation Pressure (psia) |
---|---|
11,762 | 5816 |
11,829 | 5821 |
11,847 | 5822 |
11,977 | 5859 |
12,011 | 5871 |
12,087 | 5898 |
12,141 | 5915 |
12,269 | 5973 |
12,278 | 5976 |
12,316 | 5994 |
12,345 | 6009 |
- Ex 8.6:
-
A pressure survey was carried out on a well that penetrates through the gas zone in a reservoir at FUPRE. The result of test 1 recorded a pressure of 3830 psia at 9525Â ft with fluid gradient of 0.352Â psi/ft while test 2 at 9200Â ft recorded a pressure of 3560 psia with fluid gradient of 0.118Â psi/ft. Calculate:
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Estimate the fluid contacts (GOC & OWC ) in the reservoir
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During history match, it was observed that the fluid contacts given by the geologists were wrong which was traceable to wrong fluid gradient . After careful analysis, it was observed that the oil gradient is 0.341Â psi/ft recomputed the fluid contacts and estimate the absolute relative error.
-
The thickness of the oil column
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Calculate the pressures at GOC and OWC respectively
Hint: take the water gradient as 0.445Â psi/ft and atmospheric pressure as 14.69 psia
- Ex 8.7:
-
An exploratory well penetrates a reservoir near the top of the oil column. Logs run in the well clearly located the gas-oil contact at 5200Â ft also DST test conducted on this well and sample analysis of the fluid sample collected from the same well gave reservoir pressure of 2402 psia at 5250Â ft and oil gradient of 0.35Â psi/ft the depth of the oil-water contact is uncertain because it could not be confirmed by logs.
-
Determine the probable oil-water contact
-
What is the pressure at the crest of the reservoir?
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Okotie, S., Ikporo, B. (2019). Pressure Regimes and Fluid Contacts. In: Reservoir Engineering. Springer, Cham. https://doi.org/10.1007/978-3-030-02393-5_8
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DOI: https://doi.org/10.1007/978-3-030-02393-5_8
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