1 Houston-based EOG Resources Inc. announced a horizontal Pearsall shale discovery in Atascosa County (RRC Dist. 1), Texas. The #1H Alonzo Peeler A flowed 368 bbl. of 44-degree-gravity crude, 653,000 cu. ft. of gas and 1,739 bbl. of water per day from fracture-stimulated perforations at 11,880-15,390 ft. Tested on a 28/64-in. choke, the flowing tubing pressure was 1,096 psi. The horizontal leg of the Indio Tanks Field well was drilled southward to 15,581 ft. in Arthur Gamble Survey, A-280. The true vertical depth is 11,867 ft. and bottomed in BS&E Survey, A-1307.

2 In Karnes County (RRC Dist. 2), Texas, a horizontal Austin Chalk well has been completed by Blackbrush Oil & Gas. The horizontal Labus Field well, #1H Theresa Pawelek, is producing 821 bbl. of 44.1-degree-gravity crude, 1.42 million cu. ft. of gas and 135 bbl. of water per day from fracture-stimulated perforations at 10,372-12,568 ft. Gauged on an 18/64-in. choke, the flowing casing pressure was 1,650 psi. The well is in Manuel Lopez Survey, A-181 and was drilled to 12,568 ft. The lateral bottomed about half a mile northwest at a true vertical depth of 10,160 ft. Blackbrush’s headquarters are in San Antonio.

3 A Frio gas discovery was completed by Houston-based Sandalwood Exploration LP in western San Patricio County (RRC Dist. 4), Texas. The #1 Princess Peach Unit #1 flowed 1.14 million cu. ft. of gas and 16 bbl. of 60.6-degree-gravity condensate per day. Gauged on a 10/64-in. choke, the flowing tubing pressure was 2,281 and the shut-in tubing pressure was 2,335 psi. Production is from perforations at 6,605-34 ft. and the well was drilled to 6,700 ft. on a 1,690-acre South Texas lease in Lot 30 of Julian Maria de la Garza Survey, A-8.

4 A Pearsall shale discovery in Gonzales County (RRC Dist. 1), Texas, by Penn Virginia Oil & Gas Corp., apparently extends Indio Tanks Field into Gonzales County. The #50H Cannonade Ranch South had an initial daily flowrate of 992,000 cu. ft. of gas, 140 bbl. of 51-degree-gravity condensate and 1,338 bbl. of water from 12,446-16,656 ft. After acidizing and fracturing the zone, the well had a flowing tubing pressure of 1,375 and a shut-in tubing pressure of 2,750 psi when tested on a 22/64-in. choke. The lateral was drilled southeast to a total depth of 16,715 ft., 12,159 ft. true vertical. The original pilot hole was drilled to 12,245 ft. (12,239 ft. true vertical) on a 4,013-acre lease in Section 2, Felix Taylor Survey, A-71. The surface location is just southeast of several vertical Austin Chalk oil wells. Penn Virginia’s headquarters are in Radnor, Pa.

5 In Grimes County (RRC Dist. 3), Texas, Marlin Energy Resources LLC completed a Woodbine venture in Madisonville West Field. The #1H Wheaton Cattle Co. produced 1,093 bbl. of oil, 1.55 million cu. ft. of gas and 713 bbl. of water. The 14,407-ft. well is in Timothy Jones Survey, A-33, and the true vertical depth is 9.076 ft. with a bottomhole in Joseph T. Gilbert Survey A-231. Production is from perforations at 9,722-14,450 ft. Tested on a 64/64-in. choke, the flowing tubing pressure was 370 psi. Marlon Energy’s headquarters are in Lafayette, La.

6 A Lower Frio directional gas well was completed by Samson Exploration LLC in Alta Loma East Field "in Galveston County (RRC Dist.5), Texas. The #1 Hunt Club Gas Unit flowed 4.76 million cu. ft. of gas, 185 bbl, of 50-degree-gravity condensate and 32 bbl. of water per day from perforations at 15,522-82 ft. The venture is in Section 29, William Scott Survey, A-177, and bottomed almost one mile south-southeast. The total depth is 16,537 ft. and the true vertical depth is 16,006 ft. Gauged on a 17/64-in. choke, the flowing casing pressure was 7,673 psi and the shut-in casing pressure was 9,439 psi. Samson Exploration’s headquarters are in Tulsa.

7 A vertical Lower Smackover gas completion by Southwestern Energy Production Co. in Union Parish, La., flowed 668,000 cu. ft. of gas and 112 bbl. of 62.9-degree-gravity condensate. The #1 Dean 31-22-1 produced from perforations at 9,966-10,208 ft. Gauged on an 8/64-in. choke, the flowing tubing pressure was 2,959 psi. The 10,520-ft. Ora Field well is in Section 31-22n-1e. Earlier in 2013, the Houston-based company completed a horizontal Lower Smackover Brown Dense test from an offsetting surface location as a vertical gas completion. The #2-Alt Dean 31-22-1 was drilled to 13,800 ft., 10,300 ft. true vertical. Additional completion information is not available.

8 Apache Corp. has filed plans to drill up to three exploratory tests at a new prospect in Garden Banks. Apache’s first wildcat is planned from a site in the southwestern portion of previously undrilled Garden Banks Block 169, bottoming to the south beneath Garden Banks Block 213 (OCS G31613). Up to two more ventures could be drilled from offsetting surface locations, also bottoming to the south beneath Block 213. Water depth in the area is 920 ft. The nearest production is in Garden Banks Block 171 Field, about seven miles southeast of Houston-based Apache’s first planned location at Anadarko Petroleum’s Salsa Field. In the first three months of 2013, output from seven wells totaled 2.1 million bbl. of crude, 7.8 billion cu. ft. of gas and 18,360 bbl. of water.

9 Goodrich Petroleum Corp. plans to drill two horizontal Tuscaloosa Marine shale wildcats in Wilkinson County, Miss. The Houston-based company’s #1 Cavin 11-2H will be in Section 12-2n-1w. The horizontal leg of the venture will bottom to the north-northwest beneath Section 2; the planned true vertical depth is 11,850 ft. The bottomhole will offset #1 Crosby 2-9, an 8,066-ft. dry Wilcox test abandoned in 1973. In nearby Section 20-2n-1e, Goodrich recently permitted a horizontal Tuscaloosa Marine shale test in Section 20-2n-1e, #1 CMR/Foster 20-7H. This venture has a planned true vertical depth of 12,310 ft., with a lateral bottoming one and one-third miles north beneath Section 7.

10 In Green Canyon Block 76, Anadarko Petroleum Corp. is under way at a development test at its Ticonderoga Field. The #4SS OCS G21817 is being drilled in 5,260 ft. of water. An exploration plan filed earlier this year by the Houston-based company estimates drilling time at 75 days. Offsetting the drillsite is #3SS OCS G21817, which was drilled in 2007 to 12,494 ft. The last activity in Ticonderoga Field occurred in 2008 (Block 768). Two miles northwest of #4SS OCS G21817, Noble Energy Inc. abandoned its Deep Blue prospect, #1 OCS G21813, in 2012 after failing to find commercial amounts of hydrocarbons at deeper objectives. The #1 OCS G21813 did hit hydrocarbon pay in several Miocene intervals, but more drilling was needed to determine the extent and commerciality of the pay zones encountered.

11 According to IHS Inc., Shell Oil Co. has logged oil pay at its Vicksburg A prospect on Mississippi Canyon Block 393. The #1 OCS G26254 was drilled to 26,385 ft. and hit more than 500 ft. of net oil pay. Area water depth is 7,446 ft. Shell announced that the find holds potentially recoverable resources of more than 100 million bbl. of oil equivalent. A sidetrack is planned at the discovery well to test the Corinth prospect, which lies on a separate fault block from the Vicksburg A and B discoveries. According to the Houston-based company, the Vicksburg A is a separate accumulation from the Vicksburg B discovery on adjacent DeSoto Canyon Block 353. The Vicksburg B discovery well, #1(BP) OCS G25852, was drilled to 24,790 ft. in 2008 and hit a 300-ft. hydrocarbon column. Shell is the operator of DeSoto Canyon Block 383 and the Vicksburg A discovery well with 75% interest, in partnership with Nexen Inc.

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