1 Burlington Resources Oil & Gas completed an Eagle Ford shale well as part of Eagleville Field in Karnes County (RRC Dist. 2), Texas. The Houston-based company tested #1 Genelle Unit B flowing 1,662 bbl. of 48.5-degree-gravity oil, 1.59 million cu. ft. of gas and 98 bbl. of water per day through fracture- and acid-treated perforations at 12,730-17,098 ft. Gauged on a 14/64-in. choke, the flowing tubing pressure was 6,191 psi. The new producer is on a 320-acre lease in Peter S. Elliott Survey, A-108. The new producer was horizontally drilled to 17,300 ft., 12,241 ft. true vertical and bottomed a mile northwest beneath Ramon Musquiz Survey, A-7.

2 In Eagleville Field, EOG Resources Inc. completed a horizontal Eagle Ford producer. The well is on a 397-acre lease in John F. Miller Survey, A-192, in Karnes County (RRC Dist. 2), Texas. EOG’s #1H Max Unit was tested on a 32/64-in. choke flowing 1,398 bbl. of 42-degree-gravity crude, 1.74 million cu. ft. of gas and 1,080 bbl. of water per day. Production comes from fractured perforations at 10,967-16,030 ft. after drilling to 16,165 ft., 10,957 ft. true vertical. Site log tops include Anacacho at 9,638 ft., Austin Chalk at 9,951 ft. and Eagle Ford at 10,322 ft. EOG’s headquarters are in Houston.

3 A Cotton Valley discovery has been finaled by Harding Co. in San Augustine County (RRC Dist. 6), Texas. The #1-F1SN Rebecca Black Stone flowed 1.26 million cu. ft. of gas, 45 bbl. of 52-degree condensate and 415 bbl. of water per day through perforations at 8,990-13,266 ft. Gauged on a 1-in. choke, the flowing tubing pressure was 90 psi and the shut-in tubing pressure was 525 psi. The new producer is on a 640-acre lease in Samuel D. McMahon Survey, A-28. The well was horizontally drilled to 13,375 ft. and bottomed about a mile to the northwest beneath the same survey. The Dallas-based operator’s #2-FSN Rebecca Black Stone is a direct offset to the new discovery in the same survey. The horizontal test was permitted in 2010 to 9,000 ft., and no activity has been reported at the site.

4 A horizontal James Lime producer has been completed in San Augustine County (RRC Dist. 6), Texas, in an area dominated by Haynesville shale activity.

Devon Energy Production Co. tested #2H J. Sublett Gas Unit flowing 2.12 million cu. ft. of gas, 300 bbl. of 44.6-degree-gravity oil and 500 bbl. of condensate per day. Production comes from a fracture-treated zone at 8,486-12,772 ft. Tested on a 1-in. choke, flowing and shut-in tubing pressures were 165 psi and 1,030 psi, respectively. The Angie Field well was drilled to 12,874 ft., 7.918 ft. true vertical, in Elisha Roberts Survey, A-37, and bottomed to the north beneath the Phillip Sublett Survey, A-44, at a true vertical depth of 7,918 ft. According to IHS Inc., the bottomhole offsets the operator’s #1H J. Sublett, an 18,560-ft. Haynesville well in Carthage Field. Devon is based in Oklahoma City.

5 According to IHS Inc., Houston-based SWEPI LP finaled a high-volume Upper Jurassic well as part of Oxford Field. Located in Section 29-11n-12w of DeSoto Parish, La., #1 Rocking G Farms 29 was tested flowing 23.74 million cu. ft. of gas and 510 bbl. of water per day through fracture-treated perforations at 12,763-17,065 ft. The flowing casing pressure was 8,003 psi when tested on a 25/64-in. choke. The new producer was horizontally drilled to 17,228 ft., 12,306 ft. true vertical, and bottomed a mile to the north beneath the same section. There are currently only two Jurassic (Haynesville shale) producers in the Arkla Basin reservoir, which yielded 436.6 million cu. ft. of gas and 17,610 bbl. of water in March 2011.

6 Two horizontal Haynesville shale completions by Chesapeake Operating Inc. were reported in Red River-Bull Bayou Field in DeSoto Parish, La. The #1 Awtbegood 19-14-11H flowed 18.43 million cu. ft. of gas and 217 bbl. of water daily through fracture-stimulated perforations at 12,258-16,512 ft. Gauged on a 22/64-in. choke, the flowing tubing pressure was 7,840 psi. The well was drilled to 16,615 ft., 12,139 ft. true vertical, in irregular Section 37-14n-11w. The #1 ABG 37-30-14-11H offsets #1 Awtbegood 19-14-11H to the south in the same section. The initial daily potential was 17.59 million cu. ft. of gas and 250 bbl. of water per day. Production comes from fractured perforations at 12,279-16,529 ft. after drilling to 16,645 ft., 12,245 ft. true vertical. Tested on a 22/64-in. choke, the flowing tubing pressure was 8,190 psi. Chesapeake’s headquarters are in Oklahoma City.

7 In Red River Parish, La., Encana Oil & Gas (USA) reported a horizontal Haynesville shale completion as part of Red River-Bull Bayou F. The #1 McLelland Trust 29 was tested flowing 17.04 million cu. ft. of gas and 552 bbl. of water per day through fractured perforations at 12,842-17,279 ft. The flowing casing pressure was 8,744 psi after testing on a 22/64-in. choke. The Arkla Basin completion is in Section 29-14n-10w and was drilled to 17,460 ft., 12,456 ft. true vertical, bottoming a mile south beneath the same section. Encana’s headquarters are in Calgary.

8 In Grant Parish, La., PAR Minerals Corp. completed a Wilcox wildcat that flowed 40 bbl. of 43.3-degree-gravity oil and 1 bbl. of water per day. The #1 Ivory 17 was drilled to 4,369 ft. in Section 17-7n-3w and perforated at 4,004-06 ft. Tested on an 8/64-in. choke, the flowing and shut-in tubing pressures were 290 psi and 690 psi, respectively. The Shreveport-based operator’s #3 Ivory 17 is a direct offset in the same section.

9 A Tuscaloosa Marine shale discovery was reported by Encana Oil & Gas Inc. in Amite County, Miss. The #1H Board of Education is in Section 16-1n-5e and initially flowed 373 bbl. of 37.7-degree-gravity oil, 119,000 cu. ft. of gas and 534 bbl. of water. The horizontal lateral was drilled to 16,500 ft., 11,992 ft. true vertical, and production comes from acid- and fracture-stimulated perforations between 11,977-14,900 ft. Encana assumed operations of the well from Encore Operating LP, which originally drilled the well in 2008.

10 Spooner Petroleum Co. of Ridgeland, Miss., completed a Smackover discovery in Clarke County, Miss. The #1 Donald was tested flowing 317 bbl. of 20.3-degree oil and 48 bbl. of water per day through perforations at 11,074-90 ft. and 11,096-11,108 ft. The wildcat is in Section 30-2n-18e, and was vertically drilled to 11,650 ft. Site log tops include Cotton Valley, 9,160 ft.; Buckner, 10,948 ft.; Smack-over, 11,070 ft.; and Paleozoic at 11,602 ft. Nearby recovery comes from a 1968 completion about two miles south in Section 6-1n- 18e: #1 Rolison 6-12 pumped 216 bbl. of crude daily through acidized perforations at 11,564-11,596 ft. as the sole producer in Double Creek Field. More Smackover production comes from Melvin and Melvin Northeast fields in neighboring Choctaw County, Ala. In Clarke County, shallower production comes from Eutaw between 2,600 and 3,800 ft. in Junction City Field.

11 A deepwater Mississippi Canyon (Block 348) test has been spudded at Shell Gulf of Mexico Inc.’s Appomattox prospect. The #3 OCS G19939 is part of a three-block project approved by the Bureau of Ocean Energy Management. Up to four more tests could be drilled from various surface locations on Block 348, Block 391 and Block 392. Shell’s Appomattox discovery was announced in early 2010 when the company hit 530 ft. of oil pay after drilling to 25,050 ft. An appraisal sidetrack encountered approximately 380 ft. of oil pay. According to Appomattox partner Nexen, the Block 392 discovery holds at least 250 million bbl. of oil equivalent of recoverable resources. Houston-based Shell operates and has an 80% stake in Appomattox. Nexen holds the remaining 20%.

All data in the Exploration Highlights section is based on sources believed to be reliable, but its accuracy cannot be guaranteed. The prudent investor intending to act upon any particular data is urged to verify it with all other available sources. In no way should the publication of these items be construed as an express or implied endorsement of a company or its activities.

Most land in the U.S. is divided into townships—rectangular tracts six miles square. The township, in turn, is divided into 36 numbered sections, each a one-mile square. The lines running north-south and dividing east from west are called range lines. The lines running east-west and dividing north from south are township lines.

A well in Section 15-Township 4 north-Range 3 east is abbreviated: 15-4n-3e.