Reference no: EM131438909

Assignment

Chapter 2- Basic Concepts in Reservoir Engineering

Question 1.1

The vertical exploration well Genesis-1 was drilled to a total depth of 12,500 ft offshore in the Canning Basin. During drilling no gas was found to be present in the mud but oil florescence was seen in the drill cuttings.

Prior to running the 9 5/8 inch casing string it was decided to run the modular dynamic tester (MDT) in the open hole over the sand body to help confirm the fluids present in the reservoir identified earlier from well logs.

The data obtained from the MDT survey is provided in Table 1. The data was measured "Relative to Kelly Bushing" (RKB) which was 75 ft above the mean sea level (MSL).

You are required to carry out the following. Remember, your answers should be in Field Units.

1. Identify the fluid contacts present (if any) across the formation, with depths referenced to a sub-sea (SS) datum.

2. Calculate the various fluid gradients and densities.

3. Comment on the hydrostatic pressure regime of the reservoir.

Depth	Formation
(RKB) (metres)	Pressure (psia)
3,523	4,973.0
3,528	4,974.3
3,529	4,974.6
3,530	4,974.8
3,531	4,975.1
3,532	4,975.4
3,536	4,978.3
3,540	4,982.9
3,543	4,986.3
3,546	4,989.8
3,549	4,993.2
3,556	5,002.8
3,560	5,008.5
3,570	5,023.0
3,572	5,025.9
3,586	5,046.1

Table 1. MDT survey data

Question 1.2

Emerald oil field has been discovered 50 km off the shoreline in the North-West Shelf of Western Australia in a water depth of 100 meters. Initial seismic interpretations have revealed that the reservoir is divided into two sections by a fault (Figure 1). In the first month of discovery Well A was drilled into the western flank of the structure but no traces of hydrocarbon were found. After further seismic data analysis it was decided to drill a second well (Well B) into the other side of the fault (eastern flank). From the mud-log analysis and well log interpretations it has been revealed the structure on the east side of fault contains commercially producible volumes of oil and gas. Therefore it is believed that the fault running through the structure is a sealing fault.

Figure 1 (figures are for illustration purposes only and not to scale)

While drilling Well A, a single pressure measurement was performed. At depth of 5,500 ftss the pressure was measured to be 2,534.7 psia. From the well logs run in Well B, OWC has been detected to be at 5,700 ftss. Two further pressure data were also recorded in Well B (Table 1)

Depth (ftss)	Pressure (psia)
4,575.00	2,330.27
4,675.00	2,336.95

Table 1

From the PVT analysis performed on the fluid samples taken from both wells the following data were obtained:

Bo	1.25	rb/stb
Rs	1,000	scf/stb
Bw	1.02	rb/stb
Gas expansion factor (E)	180	scf/rcf
Gas specific gravity (surface conditions)	0.7
Oil specific gravity (surface conditions)	0.8
Water surface density	64.63	lb/ft3

Table 2

a. Identify the gas-oil contact (GOC)?

b. A well test program performed on Well B produced oil with a constant flowrate of 7,000 stb/d and a corresponding gas flowrate of 10 MMscf/d. Calculate the production GOR? Then based on the GOR value you just calculated and with the knowledge that the aquifer support for the reservoir is considered to be weak, what advice you would have for the production engineer to help him/her to prevent fast decline in reservoir pressure?

Notes:

- Assume there is perfect regional aquifer connectivity.
- Both drilled wells were vertical.

Question 1.3

An offshore exploration well was drilled 100km North of Rottnest Island, in 100ft water depth, to a total depth of 3,200 ftSS. The well was logged, cased and perforated across the interval of 2,700 to 2,780 ftSS. The well produced quite steadily 1,000 barrels of oil at a water cut of 5% and a constant GOR of 300 scf/stb over a period of 8 hours.

From well logs it has been confirmed that the oil water contact is at 2,800 ftSS. An MDT survey was performed across the formation; however, only two pressure measurements were made due to tool problems.

Depth (ftSS)	Pressure (psia)	Temperature (oF)
2,450	1,184	100
2,700	1,225	100

Specific gravity of the gas produced was 0.7 relative to air at 14.7psia and 60oF and the gas deviation factor is nearly constant at 0.825 across the pressure interval of 1,150 to 1,200psia. Reservoir water was tested at surface and the density was found to be 65.40lb/ft3 with a formation volume factor of 1.022. API gravity of stock tank oil is 25.

You are required to

1. Identify the gas oil contact.
2. Estimate the height of the oil column.

Question 1.4

Analyse the reservoir production data in Table 1 and then:

• Calculate the Stock Tank Oil Initially in Place (STOIIP) from the geologist's volumetric estimate given in Table 2.
• Identify the drive mechanism(s) occurring during production.
• Estimate the bubble point pressure and Rsi and determine whether the reservoir is saturated or undersaturated.
• Calculate the recovery factor and comment on whether this value is typical of the drive mechanism interpreted from the production data.

Time	Average Reservoir Pressure	Oil Rate	Water Rate	Gas Rate	Cumulative
					Oil Production	Water Production	Gas Production
(days)	(psia)	(stb/d)	(bbl/d)	(MMscf/d)	(MMstb)	(Mbbl)	(Bscf)
0	2,900	0	0	0	0	0	0
181	2,800	60,000	0	62	11	0	11
365	2,706	60,000	0	61	22	0	23
547	2,613	60,000	0	62	33	0	34
731	2,512	60,000	0	71	44	0	46
912	2,393	59,999	2	94	55	0	60
1,096	2,220	59,993	7	148	66	1	82
1,277	1,981	42,998	24	176	75	3	112
1,461	1,735	28,472	62	170	82	11	144
1,642	1,518	19,023	113	144	86	26	173
1,826	1,342	12,689	158	111	89	51	197
2,008	1,212	8,535	176	81	91	82	214
2,192	1,117	5,888	173	58	93	114	227
2,373	1,050	4,152	155	42	93	144	236
2,557	1,000	3,556	144	36	94	171	243

Table 1. Reservoir Production Data

Porosity (Φ) =	0.20	fraction
Swr =	0.13	fraction
Boi =	1.56	rb/stb
NTG =	0.75	fraction
Thickness (h) =	37	metres
Area (A) =	14×106	m2

Table 2. Volumetric Data