Table 1.

Formation physical characteristics, produced water lift method, and fluid mixing for Milne Point and Prudhoe Bay (Alaskan North Slope) oil field samples.

Formation/Reservoir	Depth (m)c	Temperature (°C)d	Well	Injection influence in the reservoire	Artifical lift method	Fluid mixed in wellbore
Prince Creeka	700–760	7.8	PC	None	ESP	None
Schrader Bluffa	1200–1400	24–27	SB1	Mixed Water (Kuparuk, Schrader Bluff, Sag River, Ugnu, Prince Creek)	ESP	None
Schrader Bluffa			SB2	Mixed Water (Kuparuk, Schrader Bluff, Sag River, Ugnu, Prince Creek)	ESP	None
Kuparuk Rivera	1785–2150	47–70	K1	Mixed Water (Kuparuk, Schrader Bluff, Sag River, Ugnu, Prince Creek)	ESP	None
Kuparuk Rivera			K2	Prince Creek	ESP	None
Kuparuk Riverb			K3	Mixed Water (Ivishak, Kuparuk, Schrader Bluff)	Gas lift	Natural gas
Sag Rivera	2690–2730	80	SR1	None	Jet pump	PC water
Ivishakb	2750–3100	80-83	I1	Seawater	Gas lift	Natural gas
Ivishakb			I2	Seawater/Ivishak	Gas lift	Natural gas

^aMilne Point field.

^bPrudhoe Bay field.

^cApproximate mean vertical depth subsea reported in the literature.

^dAverage formation temperatures were calculated based on formation depth.

^eWater produced from a reservoir is often injected back into the same or another reservoir.