This paper was prepared for the 41st Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Dallas, Tex., Oct. 2–5, 1966. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines. Abstract The Orcutt field, Santa Barbara County, California, was discovered in 1902. The Third Zone waterflood began in 1950 with a one well pilot test. The present Third Zone waterflood was initiated in 1963. The development of the project from the pilot to its current status is reviewed. The response attributable to pilot, peripheral and pattern injection is discussed along with operating principles which are followed. It is concluded that the change from a peripheral injection plan to pattern injection has been beneficial because of the reduced project life and improved well performance. Introduction The Orcutt field is located approximately 175 miles northwest of Los Angeles, California, (Fig. 1) and 8 miles south of Santa Maria in Santa Barbara County. Careaga 10, the discovery well, was drilled in 1902 by the Western Union Oil Company (Shell Oil). Union Oil Company's first well in the Orcutt field, Hartnell 1, was completed that same year. This well, together with the discovery of the Lompoc field, nine miles south of the Orcutt area, was of particular significance as they were the forerunners to other fields that Union would produce in the Central California Coastal area. There are three productive horizons underlying the Orcutt field. These are designated as the First, Second and Third Zones. This report is concerned with water injection into the Third Zone. The present areal extent of the project is outlined in Fig. 2. RESERVOIR CHARACTERISTICS Structure The productive portion of the Orcutt Third Zone reservoir lies within a faulted anticlinal dome. Contours on top of the Third Zone, Fig. 3, show the attitude of the structure.
This pilot field test in West Texas demonstrated that tertiary oil can be mobilized and recovered by the soluble-oil flooding process. Such a tertiary application can be economic, provided the residual oil saturation after waterflooding is high enough, but application at the beginning of waterflooding has a greater economic potential. Introduction Laboratory studies have indicated that the use of soluble oil could recover substantial quantities of oil not recoverable by waterflooding. Field testing of these materials in oil recovery processes has been previously reported. Considering the potential of previously reported. Considering the potential of the process and the developing need for tertiary oil, plans were made to field test the Uniflood* process plans were made to field test the Uniflood* process at Higgs Unit, near Abilene, Tex. The Higgs Unit (Fig. 1) encompasses 350 acres in Jones County, Tex. The productive zone is the Bluff Creek sand of Permian age, at an approximate depth of 1,870 ft. The primary life of the field extended from discovery (Well 6) in March, 1951, until water injection was started in Wells 1, 3, and 7 in Oct., 1964. Waterflood History In the original developmental drilling of the field, no cores were taken. Because none of the wells penetrated the entire production interval (it was suspected that there was a water-oil contact on the western flank of the sand body), no accurate determination of reservoir size was available. It was estimated that the reservoir consisted of 1,200 acre-ft, containing an average of 908 STB of oil per acre-ft (about 1,090,000 bbl total). Primary oil production was about 334,000 bbl and secondary recovery to Jan. 1, 1969, totaled about 244,000 bbl. The waterflood was developed as a peripheral flood, with injection into Wells 1, 2, 3, 7, and 11. Wells 4, 5, and 6, the first-line producers, showed poor response and watered out early in the flood. poor response and watered out early in the flood. (Well 4 had been used for salt-water disposal before the waterflood program was begun.) Wells 4 and 6 were inactivated when they watered out, and Well 5 was plugged and abandoned because of collapsed casing. The second-line producers, Wells 8, 9, and 10, responded to the waterflood, as did the two remaining producers, Wells 12 and 13. The unit production history from 1962 through 1971 is production history from 1962 through 1971 is presented in Fig. 2. presented in Fig. 2. Pattern Selection Pattern Selection To make the best use of the existing waterflood pattern and to insure the confinement of injected pattern and to insure the confinement of injected chemicals, it was decided to redrill Well 5 and use it as the pilot-area injector. The continued water injection on the west and south sides of the field would help to move mobilized oil toward Wells 8 and 9 and possibly toward Well 4. In addition, drilling a new well would provide an opportunity to core and log the hole and to measure reservoir thickness, porosity, oil saturation, and permeability - factors porosity, oil saturation, and permeability - factors that had only been estimated previously. JPT P. 9
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