1 Hamar Associations LLC, Ojai, Calif., plans two wildcats in Kern County, Calif., approximately four miles from the nearest production in South Belridge Field. The company's #2-13 Jack Hamar will test the Monterey formation in Section 13-28s-21e, approximately 13 miles northwest of the town of Buttonwillow. The second wildcat, the #3-13 Jack Hamar in the same section, will evaluate the Etchegoin sand, essentially from the same location, with a directional well. 2 Bakersfield, Calif.-based Berry Petroleum Co. completed a Green River discovery at its #11-5-54 Ute Tribal wildcat in Section 5-5s-4w in Duchesne County, Utah. The well, six miles south of the town of Duchesne, tested at 585 bbl. of oil, 714,000 cu. ft. of gas and 1,245 bbl. of water over a 17-day period. During December, its first month of reported production resulted in an average 34 bbl. of oil, 42,000 cu. ft. of gas and 73 bbl. of water a day, says IHS Energy. Berry drilled the well to 6,380 ft. The discovery is two miles north of production from Green River on the northern flank of Berry's Brundage Canyon Field. 3 McElvain Oil & Gas Properties Inc., Denver, plans two exploratory wells aimed at Wasatch and Mesaverde gas approximately 17 miles southwest of the town of Bonanza in Uintah County, Utah. The company's #33-11 Stumpjumper-Federal lies in Section 33-11s-23e and will bottom at 7,950 ft. The #34-5 Hardtail-Federal is in neighboring Section 34 and will drill to 7,750 ft. The wells are two miles south and southwest of Rock House Field. 4 Richland County, Mont., continued to boost its reputation for producing good wells as Burlington Resources Oil & Gas Co. LP, Houston, completed a dual-lateral Bakken wildcat for 697 bbl. of oil and 147 bbl. of water a day. The #24-29H BR, in Section 29-25n-53e, is in the northwestern part of the county about 21 miles southeast of Poplar. Lateral #1 extends southwest from 9,730 to 14,199 ft. to a bottomhole location in Section 32, while lateral #2 reached northwest from 8.924 to 14,000 ft. and bottoms in Section 29. The Bakken zones were fractured. The nearest producer is another Bakken discovery two miles east. 5 Headington Oil Co. LP, Dallas, also brought in a dual-lateral horizontal Bakken discovery in eastern Richland County, Mont., in Section 1-22n-57e, pumping 392 bbl. of oil a day. The #31X-1 Halvorsen's lateral #1 reached north-northeast from 10,787 to 15,836 ft. with a true vertical depth of 10,465 ft. Lateral #2 traveled south-southeast from 9,982 to 14,293 ft. with a true vertical depth of 10,499 ft. The nearest indicated producer is a vertical Madison well in Putnam East Field more than a mile north. The nearest dual-lateral Bakken well is two miles north, where the #2-25H Coon tested at 419 bbl. of oil and 23 bbl. of water a day. 6 The horizontal Bakken play is also active in North Dakota. BTA Oil Producers, Midland, Texas, received a drilling permit for a Bakken well about eight miles southwest of Crosby in south-central Divide County, N.D. The company's #20406 JV-P Moraine 211, in Section 2-161n-98w, will be drilled almost five miles north of Moraine Field. That field produces oil from Duperow, Winnepegosis and Interlake, but there is no nearby Bakken production. 7 Zinke & Trumbo Inc., Tulsa, Okla., has scheduled a horizontal wildcat in Section 28-151n-101w in northwestern McKenzie County, N.D. At that location, the #1-28H McRae is about 2.5 miles west of Alexander Field, which produces from Madison, Duperow and Red River. A Zinke & Trumbo discovery five miles northeast tested at 725 bbl. of oil, 620,000 cu. ft. of gas and 63 bbl. of water a day on pump from an openhole Nesson (Madison) zone between 9,415 and 13,232 ft. 8 Calgary-based EnCana Oil & Gas (USA) Inc. has an indicated discovery south of Jonah Field in Sublette County in southwestern Wyoming. The #13-36-Holmes-Federal flowed 508,000 cu. ft. of gas a day from an undisclosed interval in Mesaverde with 700 psi of flowing casing pressure at a location in Section 36-28n-109w. The well is a north offset to the #4-1 Holmes-Federal in Section 1-27n-109w, which flowed 920,000 cu. ft. of gas, two bbl. of condensate and 48 bbl. of water a day from three fractured Lance intervals between 7,474 and 8,633 ft. 9 BP America Production Co., Houston, tested 2.31 million cu. ft. of gas a day from its #1-1 Willow Creek exploratory well in Section 1-16n-95w, about 19 miles south of Wamsutter in eastern Sweetwater County, Wyo. The well produces from two zones. The Lewis received a fracture treatment from 11,008-27 ft., and the Mesaverde was fractured from 11,943-94 ft. BP tested the well through a 1-in. choke. It drilled the nearly vertical well to 12,170 ft., or a measured depth of 12,161 ft. The nearest production comes from an Almond formation well on the southwestern edge of Wild Rose Field. That well tested at 1.21 million cu. ft. of gas, three bbl. of condensate and six bbl. of water from the interval between 11,263 and 11,484 ft. 10 Veteran Nebraska operator Antelope Energy Co. LLC, Kimball, Neb., has permitted a wildcat to test D and J sands to 5,100 ft. about seven miles north-northwest of Sidney in Cheyenne County, Neb. The #2-28 Federal will be in Section 28-15n-50w on the northeastern edge of the Denver-Julesburg Basin. The new well will be 1.5 miles west of a Table Field well, which has produced some 65,300 bbl. of oil, 107 million cu. ft. of gas and 71,600 bbl. of water from D sand to 4,725 ft. since 1979, reports IHS Energy. The well also is a southeast offset to the company's #1-28 Federal, a 6,900-ft. wildcat that was aimed at Pennsylvanian Missouri but was drilled, cased and shut-in last summer. 11 Jetta Operating Co., Fort Worth, tested 590,000 cu. ft. of gas a day with no water at a discovery in Garden County, Neb. The exploratory well is about six miles southwest of Lewellen. Jetta tested its #3-1 Stoker through a 14/64-in. choke with flowing casing pressure of 360 psi from D Sand perforations between 3,350-52 ft. in Section 3-15n-43w. 12 ExxonMobil Corp. scheduled a wildcat some 35 miles north of the town of Parachute, Colo., on the northern flank of the Piceance Basin. The company plans to drill its #T25X-25G Piceance Creek Unit to 15,500 ft. in Section 25-1s-97w in central Rio Blanco County to look at gas potential in the Wasatch and Mesaverde intervals. The well is less than 2.5 miles west-southwest of the company's #T33X-29G Piceance Creek Unit discovery in Section 29-1s-96w. It completed that well in 2002 for 1.92 million cu. ft. of gas, 19 bbl. of condensate and 108 bbl. of water a day from an Ohio Creek sand between 9,077-83 ft. and a Mesaverde interval between 9,389 and 13,304 ft. 13 Two wildcats are planned by EnCana Oil & Gas USA Inc. on the eastern flank of the Paradox Basin of southwestern Colorado some 10 miles south-southeast of Naturita in northern San Miguel County. Both wells will evaluate Cutler and Honaker Trail gas intervals and will be drilled directionally from the same pad in Section 14-44n-15w. The #14-22-44-15 HC Mex has a proposed 10,884-ft. total depth and the #14-12-44-15 Mex is scheduled to 10,610 ft. A mile and a half northeast, EnCana completed the #1-21 Hamilton Creek Federal for 1 million cu. ft. of gas a day from Honaker Trail and Ismay to extend Hamilton Creek Field a half-mile south. 14 Kerr-McGee Oil & Gas Corp., Oklahoma City, tested 1,200 bbl. of oil per day during initial tests from a horizontal Schrader Bluff well on its Nikaitchuq Unit in the area of Spy Island in the Beaufort Sea. The #4 Nikaitchuq well is offshore Alaska's North Slope, about four miles north of Oliktok Point. Kerr-McGee drilled the well horizontally from Section 16-14n-9e, Umiat Meridian, nearly a mile northwest of the surface location to a bottomhole location in Section 17. Kerr-McGee drilled the well from the same pad it used to complete the #1 Nikaitchuq discovery, also in Section 16. That well tested at a rate of 960 bbl. of oil a day from the deeper Sag River formation. 15 Aurora Gas LLC, Anchorage, received state approval to revise its Nicolai Creek Unit participating areas and form a new Beluga participating area along the west side of the Cook Inlet in southern Alaska. The new South Participating Area allows the company to produce gas from the Tyonek formation between 2,422 and 2,918 ft. while the Nicolai Production Unit can produce from both the Beluga and Tyonek.