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Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251120 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 10/14/2025 AK E-LINE PPROF T41129 BR 09-86 50733204480000 193062 10/28/2025 AK E-LINE Perf T41130 BRU 213-26T 50283202040000 225038 10/30/2025 AK E-LINE Perf T41131 END 1-57 50029218730000 188114 11/16/2025 READ PressTempSurvey T41132 END 2-28B 50029218470200 203006 11/15/2025 READ PressTempSurvey T41133 END 2-30B 50029222280200 208187 11/18/2025 READ PressTempSurvey T41134 END 2-52 50029217500000 187092 10/28/2025 HALLIBURTON LDL T41135 KALOTSA 10 50133207320000 224147 11/7/2025 AK E-LINE Perf T41136 MPF-92 50029229240000 198193 11/8/2025 READ CaliperSurvey T41137 MPH-01 50029220610000 190086 11/7/2025 READ CaliperSurvey T41138 MPI-14 50029232140000 204119 11/8/2025 READ CaliperSurvey T41139 MPU H-01 50029220610000 190086 11/4/2025 AK E-LINE Drift/CBL/Caliper/Packer T41138 MPU I-14 50029232140000 204119 11/8/2025 AK E-LINE RigAssist T41139 MPU J-02 50029220710000 190096 11/6/2025 AK E-LINE Caliper/Gyro T41140 NCIU A-07A 50883200270100 225094 11/1/2025 AK E-LINE CBL T41141 NCIU A-07A 50883200270100 225094 11/4/2025 AK E-LINE Perf T41141 ODSN-01A 50703206480100 216008 10/24/2025 HALLIBURTON PACKER T41142 ODSN-25 50703206560000 212030 10/23/2025 HALLIBURTON PACKER T41143 ODSN-26 50703206420000 211121 11/4/2025 HALLIBURTON PERF T41144 PBU 02-10B 50029201630200 200064 10/27/2025 HALLIBURTON RBT T41145 PBU A-24B 50029207430200 225067 10/20/2025 BAKER MRPM T41146 PBU B-05E 50029202760500 225093 10/23/2025 HALLIBURTON RBT T41147 PBU B-05E 50029202760500 225093 10/23/2025 BAKER MRPM T41147 PBU B-20A 50029208420100 212026 10/16/2025 BAKER SPN T41148 PBU F-18B 50029206360200 225099 11/5/2025 HALLIBURTON RBT-COILFLAG T41149 PCU D-10 50283202080000 225082 10/31/2025 AK E-LINE Patch T41150 PCU D-10 50283202080000 225082 10/17/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/22/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/29/2025 AK E-LINE Perf T41150 END 2-30B 50029222280200 208187 11/18/2025 READ PressTempSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:19 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU D-11 50283202090000 225088 10/16/2025 AK E-LINE CBL T41151 PCU D-11 50283202090000 225088 10/24/2025 AK E-LINE Perf T41151 Please include current contact information if different from above. 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Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp 0 Orig • New API_WeliNo l PermitNumberl WellName I WellNumber I I WellNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A '50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/S14 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/509 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-66SD12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-17B 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E 0 i• John A. Barnes Post Office Box 244027 Senior Vice President Anchorage,AK 99524 3800 Centerpolnt Dr. Suite 100 Anchorage,AK 99503 Phone:907/777-8350 Email:Jbarnes@hllcorp.com iiileorp Alaska,LLC January 12, 2015 Mr. Paul Decker,Acting Director Division of Oil&Gas SCANNED MAY 0 8 2015 State of Alaska, Dept. of Natural Resources 550 West 7th Avenue,Suite 800 Anchorage,AK 99501-13560 Ms. Cathy Foerster, Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage,AK 99501 RE: Summary Report of Well 2-30B/ME-01 Testing and Production, Dear Mr. Decker and Ms. Foerster, As requested in the AOGCC's letter of January 22, 2009, attached is a report of the well tests and allocated production for well 2-30B/ME-01 for the period of December 1, 2013 to November 30, 2014. A summary of well activity during this report period follows: • A tubing wash with water was performed on April 17, 2014. • The subsurface safety valve was repaired on October 16, 2014. A listing of the daily well production and well tests during the report period is enclosed. If you have any questions, please contact Larry Greenstein, lgreenstein@hilcorp.com or 907-777-8322. Sincerely, John. Barnes 4 ' 3 Production Allocation Data Bore Report Date Hours Oil Vol Water Vol Gas Vol Gas Lift Vol (bbls) (bbls) (mscfd) (mscfd) 2-30B/ME-01 11/30/2014 24 316 32 353 2,771 2-30B/ME-01 11/29/2014 24 318 32 354 2,760 2-30B/ME-01 11/28/2014 24 314 32 354 2,766 2-30B/ME-01 11/27/2014 24 310 32 353 2,786 2-30B/ME-01 11/26/2014 24 306 32 353 2,742 2-30B/ME-01 11/25/2014 24 307 32 343 2,756 2-30B/ME-01 11/24/2014 24 303 32 346 2,886 2-30B/ME-01 11/23/2014 24 310 32 354 2,808 2-30B/ME-01 11/22/2014 24 315 32 357 2,789 2-30B/ME-01 11/21/2014 24 364 9 451 2,771 2-30B/ME-01 11/20/2014 24 344 9 433 2,853 2-30B/ME-01 11/19/2014 24 337 9 432 2,869 2-30B/ME-01 11/18/2014 24 337 9 430 2,866 2-30B/ME-01 11/17/2014 24 346 9 442 2,873 2-30B/ME-01 11/16/2014 24 340 9 423 2,878 2-30B/ME-01 11/15/2014 24 342 9 400 3,062 2-30B/ME-01 11/14/2014 24 374 9 419 3,072 2-30B/ME-01 11/13/2014 24 370 9 451 3,007 2-30B/ME-01 11/12/2014 24 379 9 443 3,068 2-30B/ME-01 11/11/2014 24 361 9 436 2,969 2-30B/ME-01 11/10/2014 24 379 9 450 2,896 2-30B/ME-01 11/9/2014 23.83 449 11 481 2,927 2-30B/ME-01 11/8/2014 24 441 10 447 3,029 2-30B/ME-01 11/7/2014 24 462 11 480 3,043 2-30B/ME-01 11/6/2014 24 467 11 481 2,896 2-30B/ME-01 11/5/2014 24 447 11 478 2,856 2-30B/ME-01 11/4/2014 24 454 11 466 2,959 2-30B/ME-01 11/3/2014 24 448 11 487 2,945 2-30B/ME-01 11/2/2014 24 459 11 478 2,955 2-30B/ME-01 11/1/2014 24 432 11 477 2,931 2-30B/ME-01 10/31/2014 24 519 11 444 2,897 2-30B/ME-01 10/30/2014 24 519 11 444 2,900 2-30B/ME-01 10/29/2014 24 519 11 444 2,974 2-30B/ME-01 10/28/2014 24 519 11 444 3,005 2-30B/ME-01 10/27/2014 24 519 11 444 3,025 2-30B/ME-01 10/26/2014 24 517 11 441 2,981 2-30B/ME-01 10/25/2014 24 514 11 439 3,055 2-30B/ME-01 10/24/2014 24 511 10 436 2,982 2-30B/ME-01 10/23/2014 24 508 10 433 2,927 2-30B/ME-01 10/22/2014 24 505 10 431 2,908 2-30B/ME-01 10/21/2014 24 505 10 431 2,917 2-30B/ME-01 10/20/2014 24 504 10 430 3,056 2-30B/ME-01 10/19/2014 24 504 10 430 3,159 2-30B/ME-01 10/18/2014 19 399 8 340 2,393 2-30B/ME-01 10/17/2014 24 504 10 430 3,097 2-30B/ME-01 10/16/2014 13.9 292 6 249 1,827 2-30B/ME-01 10/15/2014 0 0 0 0 0 2-30B/ME-01 10/14/2014 0 0 0 0 0 2-30B/ME-01 10/13/2014 0 0 0 0 0 2-30B/ME-01 10/12/2014 0 0 0 0 0 2-30B/ME-01 10/11/2014 0 0 0 0 0 2-30B/ME-01 10/10/2014 15.1 315 6 268 3,269 2-30B/ME-01 10/9/2014 20.3 424 8 361 2,926 2-30B/ME-01 10/8/2014 24 501 10 428 3,172 2-30B/ME-01 10/7/2014 24 501 10 427 3,170 2-3 OB/ME-01 10/6/2014 24 501 10 427 3,148 2-30B/ME-01 10/5/2014 24 500 10 427 3,129 2-30B/ME-01 10/4/2014 24 500 10 427 3,117 2-30B/ME-01 10/3/2014 24 500 10 426 3,129 2-30B/ME-01 10/2/2014 24 500 10 426 3,119 2-30B/ME-01 10/1/2014 24 499 10 426 3,122 2-30B/ME-01 9/30/2014 24 499 10 425 3,080 2-30B/ME-01 9/29/2014 24 499 10 425 3,106 2-30B/ME-01 9/28/2014 24 499 10 425 3,099 2-30B/ME-01 9/27/2014 24 494 11 421 3,111 2-30B/ME-01 9/26/2014 24 489 11 417 3,126 2-30B/ME-01 9/25/2014 24 484 12 413 3,059 2-30B/ME-01 9/24/2014 24 479 12 409 3,059 2-30B/ME-01 9/23/2014 24 474 12 405 3,059 2-30B/ME-01 9/22/2014 24 469 13 400 3,039 2-30B/ME-01 9/21/2014 24 464 13 396 3,035 2-30B/ME-01 9/20/2014 24 464 13 397 3,045 2-30B/ME-01 9/19/2014 24 465 13 397 3,044 2-30B/ME-01 9/18/2014 24 465 14 398 3,026 2-30B/ME-01 9/17/2014 24 466 14 398 3,017 2-30B/ME-01 9/16/2014 24 467 14 398 3,032 2-30B/ME-01 9/15/2014 24 467 14 399 3,047 2-30B/ME-01 9/14/2014 24 468 14 399 3,080 2-30B/ME-01 9/13/2014 24 468 14 400 3,061 2-30B/ME-01 9/12/2014 24 469 14 400 3,053 2-30B/ME-01 9/11/2014 24 470 14 401 3,039 2-30B/ME-01 9/10/2014 24 470 14 401 3,035 2-30B/ME-01 9/9/2014 24 471 14 401 3,042 2-30B/ME-01 9/8/2014 24 471 14 402 3,039 2-30B/ME-01 9/7/2014 24 472 14 402 2,991 2-30B/ME-01 9/6/2014 24 472 14 403 3,081 2-30B/ME-01 9/5/2014 24 473 14 403 3,127 2-30B/ME-01 9/4/2014 24 474 15 404 3,131 2-30B/ME-01 9/3/2014 24 474 15 404 2,967 2-30B/ME-01 9/2/2014 24 475 15 404 2,941 2-30B/ME-01 9/1/2014 24 473 14 403 2,943 2-30B/ME-01 8/31/2014 24 448 10 382 2,981 2-30B/ME-01 8/30/2014 24 448 10 382 2,967 2-30B/ME-01 8/29/2014 7.73 144 3 123 804 2-30B/ME-01 8/28/2014 24 448 10 382 2,863 2-30B/ME-01 8/27/2014 24 448 10 382 2,862 2-30B/ME-01 8/26/2014 24 448 10 382 2,923 2-30B/ME-01 8/25/2014 24 448 10 382 2,902 2-308/ME-01 8/24/2014 24 448 10 382 2,861 2-30B/ME-01 8/23/2014 24 448 10 382 2,843 2-30B/ME-01 8/22/2014 24 448 10 382 2,843 2-30B/ME-01 8/21/2014 24 448 10 382 2,856 2-30B/ME-01 8/20/2014 24 448 10 382 2,890 2-30B/ME-01 8/19/2014 24 450 10 384 2,866 2-30B/ME-01 8/18/2014 24 452 10 386 2,948 2-30B/ME-01 8/17/2014 24 454 10 387 2,977 2-30B/ME-01 8/16/2014 24 456 10 389 2,921 2-30B/ME-01 8/15/2014 24 459 10 391 2,893 2-30B/ME-01 8/14/2014 24 461 10 393 2,922 2-30B/ME-01 8/13/2014 24 463 10 395 2,921 2-30B/ME-01 8/12/2014 24 465 10 396 2,897 2-30B/ME-01 8/11/2014 24 467 11 398 2,899 2-30B/ME-01 8/10/2014 24 470 11 400 2,908 2-30B/ME-01 8/9/2014 24 472 11 402 2,911 2-30B/ME-01 8/8/2014 24 474 11 403 2,931 2-30B/ME-01 8/7/2014 24 476 11 405 2,982 2-30B/ME-01 8/6/2014 24 478 11 407 3,014 2-30B/ME-01 8/5/2014 24 481 11 409 3,069 2-30B/ME-01 8/4/2014 24 482 11 410 3,082 2-30B/ME-01 8/3/2014 24 483 10 410 3,007 2-30B/ME-01 8/2/2014 24 484 10 411 3,005 2-30B/ME-01 8/1/2014 24 485 10 412 2,975 2-30B/ME-01 7/31/2014 24 500 7 425 2,897 2-30B/ME-01 7/30/2014 24 500 7 425 3,053 2-30B/ME-01 7/29/2014 24 500 7 425 3,033 2-30B/ME-01 7/28/2014 24 500 7 425 2,984 2-30B/ME-01 7/27/2014 24 500 7 425 2,982 2-30B/ME-01 7/26/2014 24 500 7 425 3,010 2-30B/ME-01 7/25/2014 24 500 7 425 3,009 2-30B/ME-01 7/24/2014 24 500 7 425 2,952 2-30B/ME-01 7/23/2014 24 500 7 425 3,001 2-30B/ME-01 7/22/2014 24 500 7 425 3,119 2-30B/ME-01 7/21/2014 24 500 7 425 3,012 2-30B/ME-01 7/20/2014 24 500 7 425 3,057 2-30B/ME-01 7/19/2014 24 500 7 425 2,980 2-30B/ME-01 7/18/2014 24 500 7 425 2,969 2-30B/ME-01 7/17/2014 24 496 8 422 2,941 2-30B/ME-01 7/16/2014 24 492 9 418 3,080 2-30B/ME-01 7/15/2014 24 487 10 415 3,094 2-30B/ME-01 7/14/2014 24 483 12 411 3,105 2-30B/ME-01 7/13/2014 24 479 13 407 3,076 2-30B/ME-01 7/12/2014 24 475 14 404 3,107 2-30B/ME-01 7/11/2014 24 471 16 400 3,126 2-3OB/ME-01 7/10/2014 24 466 17 397 3,133 2-30B/ME-01 7/9/2014 24 462 18 393 3,156 2-30B/ME-01 7/8/2014 24 458 20 390 3,129 2-30B/ME-01 7/7/2014 24 454 21 386 3,136 2-30B/ME-01 7/6/2014 24 449 22 382 3,176 2-30B/ME-01 7/5/2014 24 445 24 379 3,196 2-30B/ME-01 7/4/2014 24 441 25 375 3,162 2-30B/ME-01 7/3/2014 24 437 26 372 3,150 2-30B/ME-01 7/2/2014 24 433 27 368 3,189 2-30B/ME-01 7/1/2014 24 435 27 370 3,197 2-30B/ME-01 6/30/2014 24 501 21 426 3,203 2-30B/ME-01 6/29/2014 24 501 21 426 3,196 2-30B/ME-01 6/28/2014 24 501 21 426 3,178 2-30B/ME-01 6/27/2014 24 501 21 426 3,172 2-30B/ME-01 6/26/2014 24 501 21 426 3,159 2-30B/ME-01 6/25/2014 24 501 21 426 3,097 2-30B/ME-01 6/24/2014 24 501 21 426 3,035 2-30B/ME-01 6/23/2014 24 501 21 426 3,101 2-30B/ME-01 6/22/2014 24 501 21 426 3,165 2-30B/ME-01 6/21/2014 24 501 21 426 3,151 2-30B/ME-01 6/20/2014 24 501 21 426 3,165 2-30B/ME-01 6/19/2014 24 501 21 426 4,051 2-30B/ME-01 6/18/2014 24 501 21 426 3,955 2-30B/ME-01 6/17/2014 24 501 21 426 3,136 2-30B/ME-01 6/16/2014 24 501 21 426 3,086 2-30B/ME-01 6/15/2014 24 501 21 426 3,085 2-30B/ME-01 6/14/2014 24 501 21 426 3,114 2-30B/ME-01 6/13/2014 24 501 21 426 3,082 2-30B/ME-01 6/12/2014 24 501 21 426 3,089 2-30B/ME-01 6/11/2014 24 501 21 426 3,103 2-30B/ME-01 6/10/2014 24 501 21 426 3,105 2-30B/ME-01 6/9/2014 24 501 21 426 3,091 2-30B/ME-01 6/8/2014 24 501 21 426 3,106 2-30B/ME-01 6/7/2014 24 501 21 426 3,079 2-30B/ME-01 6/6/2014 24 503 20 429 3,103 2-30B/ME-01 6/5/2014 24 506 19 431 3,129 2-30B/ME-01 6/4/2014 24 508 18 433 2,778 2-30B/ME-01 6/3/2014 24 511 18 436 3,127 2-30B/ME-01 6/2/2014 24 513 17 438 3,139 2-30B/ME-01 6/1/2014 24 515 16 440 3,154 2-30B/ME-01 5/31/2014 24 457 18 389 3,158 2-30B/ME-01 5/30/2014 24 457 18 389 3,151 2-30B/ME-01 5/29/2014 24 457 18 389 3,130 2-30B/ME-01 5/28/2014 24 457 18 389 3,078 2-30B/ME-01 5/27/2014 24 457 18 389 3,079 2-30B/ME-01 5/26/2014 24 457 18 389 3,106 2-30B/ME-01 5/25/2014 24 457 18 389 3,123 2-30B/ME-01 5/24/2014 24 457 18 389 3,147 2-30B/ME-01 5/23/2014 24 457 18 389 3,180 2-30B/ME-01 5/22/2014 24 457 18 389 3,139 2-30B/ME-01 5/21/2014 24 457 18 389 3,138 2-30B/ME-01 5/20/2014 24 457 18 389 3,169 2-30B/ME-01 5/19/2014 24 460 17 390 3,186 2-30B/ME-01 5/18/2014 24 462 17 391 3,158 2-30B/ME-01 5/17/2014 24 465 16 392 3,119 2-30B/ME-01 5/16/2014 24 467 16 393 3,180 2-30B/ME-01 5/15/2014 24 470 15 394 3,205 2-30B/ME-01 5/14/2014 24 473 15 395 3,252 2-30B/ME-01 5/13/2014 24 475 14 396 3,212 2-30B/ME-01 5/12/2014 23.7 472 13 392 3,157 2-30B/ME-01 5/11/2014 24 480 13 398 3,173 1 2-30B/ME-01 5/10/2014 24 483 12 399 3,184 2-30B/ME-01 5/9/2014 24 485 12 400 3,201 2-30B/ME-01 5/8/2014 24 488 11 401 3,188 2-30B/ME-01 5/7/2014 24 491 11 402 3,228 2-30B/ME-01 5/6/2014 24 493 10 402 3,220 2-30B/ME-01 5/5/2014 24 496 10 403 3,231 2-30B/ME-01 5/4/2014 24 498 9 404 3,146 2-308/ME-01 5/3/2014 24 501 9 405 3,094 2-30B/ME-01 5/2/2014 24 504 8 406 3,089 2-30B/ME-01 5/1/2014 24 500 8 404 3,117 2-30B/ME-01 4/30/2014 19.95 364 6 310 2,632 2-3013/ME-01 4/29/2014 24 437 8 373 3,309 2-30B/ME-01 4/28/2014 12.52 228 4 195 1,688 2-30B/ME-01 4/27/2014 0 0 0 0 0 2-30B/ME-01 4/26/2014 0 0 0 0 0 2-30B/ME-01 4/25/2014 0 0 0 0 0 2-30B/ME-01 4/24/2014 0 0 0 0 0 2-30B/ME-01 4/23/2014 0 0 0 0 0 2-30B/ME-01 4/22/2014 0 0 0 0 0 2-30B/ME-01 4/21/2014 0 0 0 0 0 2-30B/ME-01 4/20/2014 7.7 140 2 119 1,318 2-30B/ME-01 4/19/2014 23.5 428 7 365 3,137 2-30B/ME-01 4/18/2014 10.1 184 3 157 1,327 2-30B/ME-01 4/17/2014 8.3 152 3 130 1,190 2-30B/ME-01 4/16/2014 24 437 8 373 3,162 2-30B/ME-01 4/15/2014 24 437 8 373 3,132 2-30B/ME-01 4/14/2014 24 401 8 342 3,113 2-30B/ME-01 4/13/2014 24 364 8 310 3,146 2-30B/ME-01 4/12/2014 24 327 8 279 3,133 ____ 2-30B/ME-01 4/11/2014 24 290 8 248 3,132 2-30B/ME-01 4/10/2014 24 253 8 216 3,158 2-30B/ME-01 4/9/2014 24 216 8 185 3,161 2-30B/ME-01 4/8/2014 24 235 8 201 3,164 2-30B/ME-01 4/7/2014 24 254 8 217 3,184 2-30B/ME-01 4/6/2014 24 273 8 233 3,198 2-30B/ME-01 4/5/2014 24 292 8 250 3,174 2-30B/ME-01 4/4/2014 24 311 8 266 3,190 2-30B/ME-01 4/3/2014 24 330 8 282 3,228 2-30B/ME-01 4/2/2014 24 349 8 298 3,162 2-30B/ME-01 4/1/2014 24 368 8 314 3,177 2-30B/ME-01 3/31/2014 24 444 9 379 3,255 2-30B/ME-01 3/30/2014 24 444 9 379 3,225 2-30B/ME-01 3/29/2014 24 444 9 379 3,135 2-30B/ME-01 3/28/2014 24 444 9 379 3,091 2-30B/ME-01 3/27/2014 24 441 9 377 3,055 2-30B/ME-01 3/26/2014 24 439 9 375 3,049 2-30B/ME-01 3/25/2014 24 436 9 373 3,076 2-30B/ME-01 3/24/2014 24 434 9 371 3,076 2-30B/ME-01 3/23/2014 24 432 9 369 3,086 2-30B/ME-01 3/22/2014 24 429 9 367 3,095 2-30B/ME-01 3/21/2014 24 427 9 365 3,078 2-30B/ME-01 3/20/2014 24 425 10 363 3,152 2-30B/ME-01 3/19/2014 24 422 10 361 3,152 2-30B/ME-01 3/18/2014 24 420 10 359 3,125 2-30B/ME-01 3/17/2014 24 417 10 356 3,126 2-30B/ME-01 3/16/2014 24 415 10 354 3,107 2-30B/ME-01 3/15/2014 24 413 10 352 3,115 2-30B/ME-01 3/14/2014 24 410 10 350 3,124 2-30B/ME-01 3/13/2014 24 408 11 348 3,159 2-30B/ME-01 3/12/2014 24 405 11 346 3,174 2-30B/ME-01 3/11/2014 24 403 11 344 3,162 2-30B/ME-01 3/10/2014 24 438 10 374 3,152 2-30B/ME-01 3/9/2014 24 472 9 403 3,168 2-30B/ME-01 3/8/2014 24 507 7 433 3,169 2-30B/ME-01 3/7/2014 24 501 8 428 3,158 2-30B/ME-01 3/6/2014 24 495 9 422 3,164 2-30B/ME-01 3/5/2014 24 489 9 417 3,218 2-30B/ME-01 3/4/2014 24 483 10 412 3,199 2-30B/ME-01 3/3/2014 24 477 10 407 3,179 2-30B/ME-01 3/2/2014 24 471 11 402 3,156 2-30B/ME-01 3/1/2014 24 465 11 397 3,132 2-30B/ME-01 2/28/2014 24 417 16 355 3,140 2-30B/ME-01 2/27/2014 24 417 16 355 3,170 2-30B/ME-01 2/26/2014 24 417 16 355 3,108 2-30B/ME-01 2/25/2014 24 417 16 355 3,079 2-30B/ME-01 2/24/2014 24 417 16 355 3,072 2-30B/ME-01 2/23/2014 24 417 16 355 3,125 2-30B/ME-01 2/22/2014 24 417 16 355 3,106 2-30B/ME-01 2/21/2014 24 417 16 355 3,067 2-30B/ME-01 2/20/2014 24 424 15 361 3,071 2-30B/ME-01 2/19/2014 24 431 14 367 3,095 2-30B/ME-01 2/18/2014 24 438 13 374 3,106 2-30B/ME-01 2/17/2014 24 446 11 380 3,084 2-30B/ME-01 2/16/2014 24 453 10 386 3,093 2-30B/ME-01 2/15/2014 24 460 9 392 3,112 2-30B/ME-01 2/14/2014 24 467 8 398 3,132 2-30B/ME-01 2/13/2014 24 474 7 404 3,056 2-30B/ME-01 2/12/2014 24 481 6 411 3,069 2-30B/ME-01 2/11/2014 24 488 5 417 3,056 2-30B/ME-01 2/10/2014 24 496 4 423 3,051 2-30B/ME-01 2/9/2014 24 503 3 429 3,064 2-30B/ME-01 2/8/2014 24 510 2 435 3,088 2-30B/ME-01 2/7/2014 24 517 1 442 3,055 2-30B/ME-01 2/6/2014 24 517 2 437 3,029 2-30B/ME-01 2/5/2014 24 517 2 433 3,034 2-30B/ME-01 2/4/2014 24 516 3 429 3,065 2-30B/ME-01 2/3/2014 24 516 3 425 3,060 2-30B/ME-01 2/2/2014 24 516 3 421 3,047 2-30B/ME-01 2/1/2014 24 516 4 417 3,070 2-30B/ME-01 1/31/2014 24 513 10 362 3,061 2-30B/ME-01 1/30/2014 24 513 10 362 3,073 2-30B/ME-01 1/29/2014 24 513 10 362 3,067 2-30B/ME-01 1/28/2014 24 513 10 362 3,052 2-30B/ME-01 1/27/2014 24 513 10 362 3,031 2-30B/ME-01 1/26/2014 24 513 10 362 3,046 2-30B/ME-01 1/25/2014 24 513 10 362 3,041 2-30B/ME-01 1/24/2014 24 513 10 362 3,046 2-30B/ME-01 1/23/2014 24 513 10 362 3,072 2-30B/ME-01 1/22/2014 24 513 10 362 3,049 2-30B/ME-01 1/21/2014 24 513 10 362 3,132 2-30B/ME-01 1/20/2014 24 513 10 362 3,098 2-30B/ME-01 1/19/2014 24 513 10 362 3,102 2-30B/ME-01 1/18/2014 24 513 10 368 3,127 2-30B/ME-01 1/17/2014 24 514 10 374 3,134 2-30B/ME-01 1/16/2014 24 514 11 380 3,114 2-30B/ME-01 1/15/2014 24 514 11 385 3,152 2-30B/ME-01 1/14/2014 24 515 11 391 3,129 2-30B/ME-01 1/13/2014 24 515 11 397 3,113 2-30B/ME-01 1/12/2014 24 516 11 403 3,119 2-30B/ME-01 1/11/2014 24 516 12 408 3,125 2-30B/ME-01 1/10/2014 24 516 12 414 3,146 2-30B/ME-01 1/9/2014 24 517 12 420 3,134 2-30B/ME-01 1/8/2014 24 517 12 426 3,174 2-30B/ME-01 1/7/2014 24 518 12 431 3,158 2-3013/ME-01 1/6/2014 24 518 13 437 3,119 2-30B/ME-01 1/5/2014 24 518 13 443 3,134 2-30B/ME-01 1/4/2014 24 519 13 443 3,138 2-30B/ME-01 1/3/2014 24 5I9 13 444 3,180 2-30B/ME-01 1/2/2014 24 520 13 444 3,170 2-30B/ME-01 1/1/2014 24 521 13 444 3,139 2-30B/ME-01 12/31/2013 24 527 16 449 2,980 2-30B/ME-01 12/30/2013 24 527 16 449 3,124 2-30B/ME-01 12/29/2013 24 527 16 449 3,121 2-30B/ME-01 12/28/2013 24 527 16 449 3,137 2-30B/ME-01 12/27/2013 24 527 16 449 3,142 2-30B/ME-01 12/26/2013 24 527 16 449 2,998 2-30B/ME-01 12/25/2013 24 527 16 449 3,089 2-30B/ME-01 12/24/2013 24 527 16 449 3,086 2-30B/ME-01 12/23/2013 24 527 16 449 3,080 2-30B/ME-01 12/22/2013 24 527 16 449 3,140 2-30B/ME-01 12/21/2013 24 527 16 449 3,104 2-30B/ME-01 12/20/2013 24 527 16 449 3,076 2-30B/ME-01 12/19/2013 24 526 16 449 3,102 2-30B/ME-01 12/18/2013 24 526 16 448 3,158 2-30B/ME-01 12/17/2013 24 525 15 447 3,174 2-30B/ME-01 12/16/2013 24 524 15 447 3,166 2-30B/ME-01 12/15/2013 24 523 15 446 3,140 2-308/ME-01 12/14/2013 24 522 14 445 3,196 2-30B/ME-01 12/13/2013 24 521 14 445 3,233 2-30B/ME-01 12/12/2013 24 521 13 444 3,272 2-30B/ME-01 12/11/2013 24 520 13 444 3,345 2-30B/ME-01 12/10/2013 24 519 13 443 3,392 2-30B/ME-01 12/9/2013 24 518 12 442 3,432 2-30B/ME-01 12/8/2013 24 517 12 442 3,424 2-30B/ME-01 12/7/2013 24 516 12 441 3,476 2-30B/ME-01 12/6/2013 24 514 12 439 3,451 2-30B/ME-01 12/5/2013 24 513 13 438 3,317 2-30B/ME-01 12/4/2013 24 511- 14 436 3,291 2-30B/ME-01 12/3/2013 24 509 14 434 3,272 2-30B/ME-01 12/2/2013 24 507 15 433 3,285 2-30B/ME-01 12/1/2013 24 505 16 431 3,265 Well Test Data _ Fluid Oil Water Gas Gas Lift Gas Lift Test Start Flow Flow Flow Flow Bore Date Hours Rate Rate Rate Rate Rate Press Chic (bpd) (bpd) (bpd) (mscfd) (mscfd) (psi) 2-30B/ME-01 11/22/2014 4 421 387 34 297 3,386 1,147 176 2-30B/ME-01 11/9/2014 4 449 439 10 375 6,125 1,138 176 2-30B/ME-01 10/27/2014 4 531 519 11 444 3,384 1,131 176 2-30B/ME-01 10/22/2014 4 515 505 10 431 3,413 1,129 176 2-30B/ME-01 9/28/2014 4 509 499 10 425 3,362 1,084 176 2-30B/ME-01 9/21/2014 4 477 464 13 396 3,313 1,070 176 2-30B/ME-01 9/1/2014 4 489 475 15 404 3,428 1,090 176 2-30B/ME-01 8/20/2014 4 458 448 10 382 3,322 1,066 176 2-30B/ME-01 8/5/2014 4 491 481 11 409 3,422 1,096 176 2-30B/ME-01 7/17/2014 4 507 500 7 425 3,315 1,064 176 2-30B/ME-01 7/2/2014 4 460 433 27 368 3,557 1,110 176 2-30B/ME-01 6/7/2014 4 522 501 21 426 3,456 1,082 176 2-30B/ME-01 6/1/2014 4 531 515 16 440 3,504 1,113 176 2-30B/ME-01 5/20/2014 4 475 457 18 389 3,522 1,116 176 2-30B/ME-01 5/2/2014 4 512 504 8 406 3,386 1,079 176 2-30B/ME-01 4/15/2014 4 445 437 8 373 3,469 1,087 176 2-30B/ME-01 4/8/2014 4 223 216 8 185 3,475 1,096 176 2-30B/ME-01 3/28/2014 4 452 444 9 379 3,404 1,074 176 2-30B/ME-01 3/11/2014 4 414 403 11 344 3,495 1,092 176 2-30B/ME-01 3/7/2014 4 514 507 7 433 3,506 1,096 176 2-30B/ME-01 2/20/2014 4 433 417 16 355 3,402 1,076 176 2-30B/ME-01 2/7/2014 4 518 517 1 442 3,373 1,066 176 2-308/ME-01 1/19/2014 4 523 513 10 362 3,392 1,072 176 2-30B/ME-01 1/5/2014 4 531 518 13 443 3,247 1,085 176 2-30B/ME-01 12/20/2013 4 544 527 16 449 3,397 1,071 176 2-30B/ME-01 12/7/2013 4 528 516 12 441 3,459 1,075 176 • • • bp • RECEIVED0 JUN 1 7 2014 Katrina GarnerBP Exploration(Alaska)Inc. / 900 Benson Manager,Base Management AOGCC P.O.Box East 196612 Boulevard BP Exploration Alaska Anchorage,Alaska 99519-6612 (907)561-5111 June 16, 2014 Cathy Foerster HN� I)` ' Commissioner and Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #10 Anchorage, Alaska, 99501-3539 RE: Permanent gas oil ratio waiver for the Duck Island Unit 2-30B/ME-01 (PTD 208-187) well. Dear Mrs. Foerster: On May 28, 2010 Alaska Oil and Gas Conservation Commission (AOGCC) issued a permanent gas oil ratio (GOR) waiver to allow Duck Island Unit 2-30B/ME-01 well (Minke) to produce at GOR in excess of twice its initial GOR. In support of the permanent GOR waiver request BP Exploration (Alaska) Inc. (BPXA), based on analysis of data available at the time, indicated that the Minke well was producing from an accumulation with a most likely original oil in place (OOIP) volume of approximately 3.5 million barrels of oil (MMBO) and total anticipated recovery of approximately 12% under primary depletion. In a letter dated May 16, 2014 the AOGCC noted that the Minke well has exceeded BPXA's original recovery estimate with production to date of approximately 1 MMBO. The AOGCC also requested BPXA submit geotechnical and engineering data and analyses of the oil accumulation being drained by Duck Island Unit 2-30B/ME-01 (Minke) well. In response to that request, please find the enclosed map (Figure 1) and cross section (Figure 2) of the Minke fault blocks and estimates of the associated in place oil volumes (originally submitted to AOGCC with a letter dated August 21, 2009), reservoir pressure trend of the Minke well (Figure 3), and material balance analyses of the Minke accumulation (Figures 4 and 5). Volumetric analysis based on data collected in the Minke well indicates in place volumes of: , • S • Approximately 3.5 MMBO in the Sag River Formation in the East fault block assuming a shared oil-water contact (OWC) between the Sag River and Ivishak Formations at 9927 ft. • Approximately 5.2 MMBO in the Sag River Formation in the East fault block assuming the OWC occurs at the spill point of 9975 ft. • Possibility of 1 .3 MMBO in the Sag River Formation in the unpenetrated West fault block assuming it is oil saturated and the OWC occurs at the spill point of 9927 ft. Material balance analysis based on Minke production and reservoir pressure data through 2013 was consistent with production from an accumulation of approximately 3.6 MMBO. Based on a SBHP measurement made April 27, 2014, reservoir pressure appears to have stabilized at approximately 1820 psig. Although additional pressure monitoring will be required to confirm this trend, this stabilization may be the result of the initiation of connectivity with another source of reservoir energy. Although there are several potential sources of energy that may be providing this pressure support including connectivity with additional hydrocarbon volume in either the East or West Minke fault blocks or aquifer support from Sag Delta North, the magnitude of the support is consistent with approximately 1 .3 MMBO through a leaking barrier such as a fault. The rising GOR trend and rapidly falling SBHP trends from the start of production through early 2010 are consistent with typical characteristics of production from a relatively small oil accumulation under primary depletion. While the increasing GOR trend of typical reservoirs produced under depletion drive eventually reverses as evolved gas is depleted, the GOR reversal observed in the Minke well was atypically abrupt, coincident with a reduction in the rate of reservoir pressure decline, and followed by several years of sustained low GOR oil production (the Minke well has not produced above twice the initial GOR since February 2010). This production behaviour may be suggestive of segregation of evolved gas and the formation of an expanding secondary gas cap providing pressure support for the reservoir. Mechanisms other than the formation of a secondary gas cap may be able to account for the better than expected primary recovery from the Minke well but are unlikely based on the available production data. Aquifer support, as mentioned previously, is a potential source of reservoir energy but sustained production at water cut of less than 5% is not indicative of significant aquifer influx. Similarly, a larger hydrocarbon volume in place would result in recovery factors more typical for production under depletion drive, however significantly greater gas production than observed would be required to match the measured reservoir pressure trend. • • • BPXA will continue to monitor and evaluate Minke production and reservoir pressure trends in an effort to confirm the in place volume and recovery mechanism. If you have any questions, please contact Tanner Gansert (907-564-5183) Sincerely, 7)644.,-,4 "e7,144-VAL Katrina Garner cc: R. L. Skillern, BP Endicott File l S S N/1�� 1 IF .Niall' W ._,..,.._.. - 8 X0170 S Y 1W ' ��\\�1\��', \M - =unite �, 1� 4if1�Eato teals-"7.. .. ��� 4'ivar A 411011° vo iw-- -24/M-12 2 ti . 1111 Sag Delta Nort 'bib.- illk 1, .6810 STATUTE ATEES STATUTE MILES Full Seal 26a9FEEt Figure 1 : Minke Area Map and Line of Section • West East West fault block East fault block A A, • Post(llti'C 9977' Poss G\VC 9977' Poc<Spill as Logged in Ivishak Point 9927' "3,SM4,60 � Poss Spill Pont Possible �i 3 � �S�rlP z. n�IC c°'S' m mbo STOI I P X00 Puss ble"1.7 mrnbuSTOIIP e mmbotilcnlN '0.2 mmbo STO I n Sag USS I�isna<O'AC_-9927 Ivisliak CSVC2—100_ 5 to 1 Figure 2: Minke Cross Section • • 5000 4500 4000 3 500 • w E F 3000 a 2500 I �' • 2000 • d a 1500 1000 500 0 Jan-09 Jan-10 Jan-11 Jan-12 Jan-13 Jan-14 Figure 3: Minke Reservoir Pressure Trends . i r 5000 Tank Pressure ❑ MINKE : History :■ -e-MINKE . Simulation d 3000 C v4 F ❑ �� ti 1000 04/01/2009 07/16/2010 10/31/2011 02/13/2013 05/31/2014 Time (date m/d/v Figure 4: Material Balance History Match of 3.6 MMBO in Place Reservoir • • 5000 rank Pressure 0 MINKE : History ,. --MINKE : Simulation G 3000 4 4. E ❑ ,, ❑ U I 200: 11 1000 04/01/2009 07/16/2010 10/31/2011 32/13/2_x13 03/31/2019 Time (date m/d/v Figure 5: Material Balance History Match of 3.5 MMBO in Place Reservoir with leaking connectivity to an accumulation of an additional 1 .3 MMBO dam\ oa • �_3 y CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7009 2250 0004 3911 3521 May 16, 2014 Ms. Katrina Gardner Manager, Base Management BP Exploration(Alaska) Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Permanent gas oil ratio waiver for the Duck Island Unit 2-30B/ME-01 (PTD 208-187) well. Dear Ms. Gardner: On May 28, 2010, the Alaska Oil and Gas Conservation Commission (AOGCC) issued Conservation Order 630 (CO 630) granting a permanent waiver of the gas oil ratio (GOR) limits imposed by 20 AAC 25.240(a)to allow the Duck Island Unit(DIU)2-30B/ME-01 well (hereinafter the Minke well) to produce at a GOR of in excess of twice the initial GOR for the well. In support of its request, BP Exploration(Alaska)Inc. (BPXA) represented that recovery from the well was expected to be around 400,000 barrels of oil (BO) and that such small reserves did not justify the drilling of an injector to support the Minke well. The reserves accessible to the Minke well appear to be far greater than BPXA' representation. To date the Minke well has produced nearly 1 million BO (MMBO) and is still producing 450-500 barrels of oil per day (BOPD). Various decline curve analysis methods indicate that the ultimate recovery, assuming an economic limit of 100 BOPD, from this well will likely be 2 to 2.5 MMBO. Based on the 3.5 MMBO original oil in place estimated at the time CO 630 was issued, the Minke well is going to recover in excess of 60%of the original oil in place. Though some reservoirs expect recovery factors of 60% or more, such reservoirs all utilize some form of enhanced recovery operations. The AOGCC requests BPXA to submit new geotechnical and engineering data and analyses of the oil accumulation being drained by the Minke well, as well as any other information you deem appropriate. In accordance with 20 AAC 25.300 you have 30 days from receipt of this letter to respond. Any questions should be directed to Mr. Dave Roby(793-123 or dave.roby(a,alaska.gov)of my staff. Sincerely, /at&t/74 -- Cathy P.Foerster Commissioner, Chair • DATE: December 21, 2016 TO: File FROM: Jody Colombie RE: Docket No OTH-14-013 The AOGCC is satisfied with response and docket is closed. DAT A SUBMITTAL COMPLIANCE REPORT 2/8/2013 Permit to Drill 2081870 Well Name /No. DUCK IS UNIT MPI 2- 30B /ME -01 Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 22228 -02 -00 MD 14207 TVD 10219 Completion Date 4/4/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: DIR, GR, RES, PWD, IFR, CASANDRA, DIR, GR, RES, PWD, NEU /D (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / • Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Rpt f Report: Final Well R Open 4/9/2009 Final Well Report, Gen Infom Daily Summ, Morn Reps, Bit Rec, Mud Reps, Show Reps, Days vrs Depth, Sample Reps, Calibration Daily ED),X Pdf 17798 Report: Final Well R 0 14207 Open 4/9/2009 Final Well Report, Gen Infom Daily Summ, Morn Reps, Bit Rec, Mud Reps, Show Reps, Days vrs Depth, Sample Reps, Calibration Daily with Mud Logs in PDS graphics Log V Mud Log 2 Col 5859 14207 Open 4/9/2009 MD Formation Eval Log Log •• Mud Log 5 Col 5859 14207 Open 4/9/2009 MD Formation Eval Log Log Mud Log 2 Col 5431 10218 Open 4/9/2009 TVD Formation Eval Log Log ' Mud Log 2 Col 5859 14207 Open 4/9/2009 MD Gas Ratio Log 410 Log Mud Log 5 Col 5859 14207 Open 4/9/2009 MD Gas Ratio Log Log / Mud Log 5 Col 5431 10218 Open 4/9/2009 TVD Gas Ratio Log Log Mud Log 1 Col 5859 14207 Open 4/9/2009 MD Gas Ratio Log Log Mud Log 2 Col 5431 10218 Open 4/9/2009 TVD Gas Ratio Log Log .e Mud Log 1 Col 5431 10218 Open 4/9/2009 TVD Gas Ratio Log Log Mud Log 2 Col 5859 14207 Open 4/9/2009 MD Drilling Engineering Log ED %+C / Las 17872 Induction /Resistivity 5750 14207 Open 4/20/2009 Dens, Corr, RPM, NPHI, RAM, RHOB, ROP DATA SUBMITTAL COMPLIANCE REPORT 2/8/2013 Permit to Drill 2081870 Well Name /No. DUCK IS UNIT MPI 2- 30B /ME -01 Operator BP EXPLORATION (ALASKA) INC API No. 50 -029- 22228 -02 -00 MD 14207 TVD 10219 Completion Date 4/4/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N Log t./ See Notes OTH Col 13794 14131 Open 4/20/2009 Stethoscope 675, Formation Press while drilling Recoded Mode. 8- Mar -2009 Log L/` Induction /Resistivity 2 Blu 5750 14192 Open 4/20/2009 TVD Scope Service Field Print 7- Mar -2009 Log .001- Induction /Resistivity 2 Blu 5750 14192 Open 4/20/2009 MD Scope Service Field Print 7- Mar -2009 Rpt See Notes 2 13790 14140 Open 4/20/2009 Stethoscope Report • ED C Lis 18283 Induction /Resistivity 5719 14207 Open 7/20/2009 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD, DRHO, NPHI, TRPM Log V Induction /Resistivity 25 Blu 5750 14192 Open 7/20/2009 MD Scope Service Log Induction /Resistivity 25 Blu 5750 14192 Open 7/20/2009 TVD Scope Service ED LA Asc Directional Survey 0 14207 Open Rpt Directional Survey 0 14207 Open ED `''C Asc Directional Survey 0 14207 Open Rpt Directional Survey 0 14207 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION ,� 410 Well Cored? IS Daily History Received? 01 1 " N Chips Received? "Me Formation Tops Q N Analysis .41'7'IT' Re ceived? Comments: `S' Compliance Reviewed By: Date: b p ! SECEIVED FEB 072013 AOGCC 0 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519 -6612 Main 907 564 5111 Febuary 5 2013 P1TD eA08 r 8 7 Mr. Bill Barron, Director Division of Oil & Gas State of Alaska, Dept. of Natural Resources 550 West 7 Avenue, Suite 800 Anchorage, AK 99501 -3560 Mrs. Cathy Foerster, Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Summary Report of Well 2- 30B /ME -01 Testing and Production Dear Mr. Barron / Mrs. Foerster, As requested in the AOGCC's letter of January 22, 2009 attached is a report of the well tests and allocated production for well 2- 30B /ME -01 for the period of December 1, 2011 to November 30, 2012. A summary of interventions during this report period follows: • A tubing wash with water was performed on May 30, 2012. A listing of the daily well production and well tests during the report period is enclosed. Should you have any questions, please contact Josiah lgwe at (907) 564 -4753. Sincerely, 1<,,,,tittimo Katrina Cooper cc: Eko Apolianto Josiah Igwe Endicott Files • • Production Allocation Data Water Report Oil Vol Vol Gas Vol Gas Lift Vol Bore Date Hrs (bbls) (bbls) (mscfd) (mscfd) 2- 30B/ME -01 11/30/2012 24 413 3 352 2,976 2- 30B /ME -01 11/29/2012 24 413 3 352 2,946 2- 30B /ME -01 11/28/2012 24 413 3 352 2,992 2- 30B /ME -01 11/27/2012 24 413 3 352 2,968 2- 30B /ME -01 11/26/2012 24 413 3 352 2,866 2- 30B /ME -01 11/25/2012 24 433 5 370 2,943 2- 30B /ME -01 11/24/2012 24 452 6 388 2,990 2- 30B /ME -01 11/23/2012 24 472 7 405 3,007 2- 30B /ME -01 11/22/2012 24 492 9 423 3,003 2- 30B /ME -01 11/21/2012 24 511 10 440 3,010 2- 30B /ME -01 11/20/2012 24 531 11 458 3,011 2- 30B /ME -01 11/19/2012 24 534 11 455 3,003 2- 30B /ME -01 11/18/2012 24 537 10 453 3,032 2- 30B /ME -01 11/17/2012 24 541 10 450 2,994 2- 30B /ME -01 11/16/2012 24 544 10 447 3,033 2- 30B /ME -01 11/15/2012 24 548 9 444 2,965 2- 30B /ME -01 11/14/2012 24 551 9 442 2,994 2- 30B /ME -01 11/13/2012 24 555 8 439 2,959 2- 30B /ME -01 11/12/2012 24 558 8 436 2,937 2- 30B /ME -01 11/11/2012 24 562 8 433 2,994 2- 30B /ME -01 11/10/2012 24 565 7 431 3,358 2- 30B /ME -01 11/9/2012 24 568 7 428 2,987 2- 30B /ME -01 11/8/2012 24 572 6 425 2,985 2- 30B /ME -01 11/7/2012 24 575 6 423 2,985 2- 30B /ME -01 11/6/2012 24 579 6 420 3,042 2- 30B /ME -01 11/5/2012 24 582 5 417 3,046 2- 30B /ME -01 11/4/2012 24 586 5 414 3,031 2- 30B /ME -01 11/3/2012 23.9 581 5 418 2,989 2- 30B /ME -01 11/2/2012 16 388 4 284 2,009 2- 30B /ME -01 11/1/2012 24 582 6 433 2,827 2- 30B /ME -01 10/31/2012 24 573 9 488 2,866 2- 30B /ME -01 10/30/2012 24 573 9 488 2,871 2- 30B /ME -01 10/29/2012 24 573 9 488 2,827 2- 30B /ME -01 10/28/2012 24 573 9 488 2,795 2- 30B /ME -01 10/27/2012 24 573 9 488 2,767 2- 30B /ME -01 10/26/2012 24 573 9 488 2,745 2- 30B/ME -01 10/25/2012 24 573 9 488 2,754 2- 30B /ME -01 10/24/2012 24 . 573 9 488 2,721 2- 30B /ME -01 10/23/2012 24 573 9 488 2,731 L8S'Z 1715 8 Z09 17Z ZIOZ /6/6 10 W /80E L65`Z US 8 109 17Z Z1OZ /Ot /6 TO 31A1/80E - Z S85'Z ?1S 8 009 17Z Z10Z /11/6 10 - 3 W /80£ - Z 6175'Z TES 8 665 17Z Z10Z /Z1 /6 10 - Z SZS'Z 115 8 86S 17Z ZlOZ /EZ /6 10 W /80E - Z ZZS'Z 115 8 865 17Z ZTOZ /171/6 10 31A1/80£ Z£9'Z 115 8 86S 17Z ZtOZ /St /6 10 /80£ - Z L65'Z 115 8 865 17Z ZtOZ /91/6 10 - 3 W /80£ EEL'? 115 8 86S 17Z ZtOZ /Lt /6 10 80L`Z 115 8 86S 17Z ZIOZ /81/6 10 - 3 W /80E - Z 8ZL'Z 115 8 865 17Z Z10Z /61/6 10 W /80E-Z 1 Z1L'Z ITS 8 86S 17Z ZIOZ /0Z/6 10-3W /80£ - Z SIL'Z ITS 8 865 17Z Z10Z /tZ /6 10 - Z 9ZL'Z ITS 8 86S 17Z ZtOZ /ZZ /6 t0 - Z ZZL'Z 11S 8 86S 17Z Z10Z /EZ /6 t0 /80£ - ? 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S617 6S 819 17Z tTOZ /61 /Z1 T0 - Z • S s t . • Well Test Data Bore Run HRS Total Oil Water Form Gas Gas Chk Date Fluid Rate Rate Gas Lift Lift (beans) Rate bpd bpd Rate Rate Pres bpd mscfd (mscfd) (psi) 2- 30B/ME -01 11/26/12 4. 417 413 3 352 3,146 1,107 176. 2- 30B/ME -01 11/20/12 4. 542 531 11 458 3,186 1,062 176. 2- 30B/ME -01 11/4/12 4. 590 586 5 414 3,179 1,019 176. 2- 30B/ME -01 10/22/12 4. 581 573 9 488 3,034 1,069 176. 2- 30B/ME -01 10/16/12 4. 471 463 8 395 3,012 1,067 176. 2- 30B/ME -01 10/9/12 4. 476 422 54 299 3,119 1,074 176. 2- 30B/ME -01 10/5/12 4. 573 562 10 480 3,078 1,070 176. 2- 30B/ME -01 9/13/12 4. 607 598 8 511 3,112 1,083 176. 2- 30B/ME -01 9/3/12 4. 613 607 6 518 2,978 1,034 176. 2- 30B/ME -01 8/25/12 4. 620 603 17 515 2,918 1,009 176. 2- 30B/ME -01 8/7/12 4. 669 648 21 24 2,896 969 176. 2- 30B/ME -01 8/1/12 4. 1,005 975 30 68 2,989 979 176. 2- 30B/ME -01 7/20/12 4. 704 683 21 32 3,048 1,102 176. 2- 30B/ME -01 7/16/12 14. 747 702 45 497 2,980 1,083 176. 2- 30B/ME -01 7/9/12 4. 916 907 9 773 2,906 1,095 176. 2- 30B/ME -01 6/11/12 4. 666 646 20 552 2,962 1,129 176. 2- 30B/ME -01 6/4/12 4. 542 522 21 446 2,970 1,132 176. 2- 30B/ME -01 5/31/12 4. 454 452 2 386 2,963 1,164 176. 2- 30B/ME -01 5/19/12 4. 479 474 5 405 2,948 1,075 176. 2- 30B/ME -01 5/10/12 4. 511 506 5 16 2,980 1,059 176. 2- 30B/ME -01 4/26/12 4. 519 517 2 53 2,997 1,052 176. 2- 30B/ME -01 4/15/12 4. 517 509 8 55 3,003 1,046 176. 2- 30B/ME -01 4/9/12 4. 525 523 3 99 2,898 1,034 176. 2- 30B/ME -01 3/18/12 4. 553 549 4 87 3,040 1,055 176. 2- 30B/ME -01 3/16/12 4. 566 562 5 101 3,081 1,064 176. 2- 30B/ME -01 3/6/12 4. 548 543 5 40 3,145 1,089 176. 2- 30B/ME -01 2/17/12 4. 592 588 4 52 3,218 1,126 176. 2- 30B/ME -01 2/9/12 4. 603 579 24 63 3,226 1,095 176. 2- 30B/ME -01 1/20/12 4. 613 612 0 523 3,363 1,123 176. 2- 30B/ME -01 1/6/12 4. 620 608 12 67 3,385 1,136 176. 2- 30B/ME -01 12/19/11 4. 674 613 61 524 3,399 1,144 176. 2- 30B/ME -01 12/5/11 4. 719 685 34 94 3,350 1,135 176. • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 201 5EP 2 0 ZUl Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 0 g b nl E .-Q l Anchorage, Alaska 99501 3 0 I� Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Endicott Row 2 Date: 03/28/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END2 -02 / P -18 1860630 50029215680000 15.0 3.0 0.5 8/28/2010 1.70 9/29/2010 END2 -04 / M -19 1860820 50029215850000 4.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -06 / J -22 1870180 50029216990000 2.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -08 / K -16 1880040 50029217710000 1.5 0.1 0.5 9/2/2010 3.40 9/29/2010 END2 -12 / 0-16 1921170 50029223020000 0.5 1.0 0.0 9/2/2010 NA 3/28/2012 END2 -14 / 0 -16 1861490 50029216390000 2.5 3.0 0.5 9/2/2010 1.70 9/28/2010 END2 -16 / M -16 1881340 50029218850000 2.0 0.5 0.5 9/2/2010 1.70 9/28/2010 END2 -18 / L -16 1900430 50029220320000 2.0 0.3 0.5 9/2/2010 2.60 9/28/2010 END2 -20 / L -15 1900600 50029220480000 5.0 3.0 0.5 8/28/2010 3.40 9/28/2010 END2 -22 / L -14 1890340 50029219310000 5.0 5.0 0.5 8/28/2010 6.80 9/28/2010 END2 -24 / M -12 1931730 50029224180000 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -26 / N -14 1880550 50029218150000 2.0 1.8 0.5 9/2/2010 1.70 9/28/2010 END2 -28B / 0-19 2030060 50029218470200 0.5 NA 0.5 NA 1.70 9/2812010 �7END2 -30B / ME -01 2081870 50029222280200 3.0 3.0 0.5 8/28/2010 2.60 9/28/2010 END2 -32 / SN -03 1901190 50029220840000 3.0 2.0 0.5 8/28/2010 2.60 9/28/2010 END2 -34 / P -14 1861720 50029216620000 1.0 NA 1.0 NA 12.80 9/25/2010 END2 -36 / 0 -14 1900240 50029220140000 5.0 3.0 0.5 8/28/2010 2.55 9/25/2010 END2 -38 / SN -01 1901290 50029220900000 3.0 4.0 0.5 8/28/2010 1.70 9/25/2010 END2 -40 / S -22 1941520 50029225270000 15.0 13.0 0.5 9/2/2010 4.00 9/25/2010 END2 -42 / P -13 1881450 50029218920000 5.0 4.0 0.5 8/28/2010 2.55 9/25/2010 END2 -44A / 0-11 1970710 50029217670100 0.5 NA 0.5 NA 22.10 10/5/2010 END2 -46B / S -13 1971370 50029219210200 4.0 1.0 0.5 9/2/2010 3.40 9/25/2010 END2 -48 / 0-13 1951660 50029226120000 2.0 2.0 0.5 8/28/2010 1.70 9/25/2010 END2 -50 / U-08 1930670 50029223670000 2.0 1.0 0.5 8/28/2010 1.70 9/25/2010 END2 -52 / S -14 1870920 50029217500000 1.0 0.3 0.5 9/2/2010 0.85 9/25/2010 END2 -54 / 0-12 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 END2 -56A / EI01 1980580 50029228630100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S-09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 END2 -62 / Q-17 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2-64 / U -10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 END2 -66 / SD -12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 END2 -68 / S -17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2 -70 / U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 • • Janet Weiss Head of Resource Management - Alaska Phone: (907) 564 -5240 Fax: (907) 564 -4461 Email Janet.Weiss @bp.com Web: www.bp.com December 15 2011 ^ - 187 Mr. Bill Barron, Director Division of Oil & Gas State of Alaska, Dept. of Natural Resources RECEIVELy 550 West 7 Avenue, Suite 800 Anchorage, AK 99501 - 3560' 21191 Alaska & Gas Mr. John Norman, Commissioner Oil n.1uSS10n Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Summary Report of Well 2- 30B /ME -01 Testing and Production Gentlemen, As requested in the AOGCC's letter of January 22, 2009 attached is a report of the well tests and allocated production for well 2- 30B /ME -01 for the period of December 1, 2010 to November 30, 2011. A summary of interventions during this report period follows: • A deep gas lift valve design was run on Dec 15, 2010. • A diesel brush and flush was performed on Apr 8, 2011. • A diesel tubing flush was performed on June 9, 2011. • A tubing wash with water was performed on Nov 9, 2011. A listing of the daily well production and well tests during the report period is enclosed. Should you have any questions, please contact Jennifer McLeod at (907) 564 -5764. Sincerely, anet Weiss cc: Katrina Cooper Jennifer McLeod Endicott Files • • . . Production Data Water Gas Report Oil Vol Vol Vol Gas Bore Date Hrs (bbls) (bbls) (mscfd) Lift Vol 2-30B/ME-01 11/30/2011 24 720 10 148 3,084 2- 30B /ME -01 11/29/2011 24 720 10 148 3,072 2- 30B /ME -01 11/28/2011 24 720 10 148 3,053 2-30B/ME-01 11/27/2011 24 726 12 141 3,173 2-30B/ME-01 11/26/2011 24 732 13 134 3,175 2-30B/ME-01 11/25/2011 24 738 15 127 3,163 2- 30B /ME -01 11/24/2011 24 719 24 160 3,211 2- 30B /ME -01 11/23/2011 24 699 34 192 3,198 2- 30B /ME -01 11/22/2011 24 680 43 224 3,194 2- 30B /ME -01 11/21/2011 23 640 50 249 3,072 2-30B/ME-01 11/20/2011 13 350 33 158 1,593 2-30B/ME-01 11/19/2011 14 371 42 192 1,901 2- 30B /ME -01 11/18/2011 24 602 80 354 3,152 2- 30B /ME -01 11/17/2011 24 582 89 386 3,110 2-30B/ME-01 11/16/2011 24 563 98 419 3,107 2-30B/ME-01 11/15/2011 24 543 107 451 3,167 2- 30B /ME -01 11/14/2011 5 112 22 93 629 2- 30B /ME -01 11/13/2011 0 0 0 0 0 2- 30B /ME -01 11/12/2011 0 0 0 0 0 2-30B/ME-01 11/11/2011 0 0 0 0 0 2- 30B /ME -01 11/10/2011 0 0 0 0 0 2- 30B /ME -01 11/9/2011 0 0 0 0 0 2- 30B /ME -01 11/8/2011 0 0 0 0 0 2- 30B /ME -01 11/7/2011 0 0 0 0 0 2-30B/ME-01 11/6/2011 0 0 0 0 0 2- 30B /ME -01 11/5/2011 0 0 0 0 0 2- 30B /ME -01 11/4/2011 0 0 0 0 0 2-30B/ME-01 11/3/2011 0 0 0 0 0 2- 30B /ME -01 11/2/2011 0 0 0 0 0 2- 30B /ME -01 11/1/2011 0 0 0 0 0 2-30B/ME-01 10/31/2011 10 265 2 226 1,162 2- 30B /ME -01 10/30/2011 14 368 3 313 1,733 2- 30B /ME -01 10/29/2011 24 614 5 523 2,870 2- 30B /ME -01 10/28/2011 24 614 5 523 2,826 2- 30B /ME -01 10/27/2011 24 607 5 517 2,842 2- 30B /ME -01 10/26/2011 24 599 5 511 2,858 2- 30B /ME -01 10/25/2011 24 592 5 505 2,887 2- 30B /ME -01 10/24/2011 24 585 5 499 2,883 2- 30B /ME -01 10/23/2011 22 530 5 452 2,574 2- 30B /ME -01 10/22/2011 24 571 5 486 2,780 2- 30B /ME -01 10/21/2011 24 564 5 480 2,793 2- 30B /ME -01 10/20/2011 24 557 5 474 2,830 2- 30B /ME -01 10/19/2011 24 550 5 468 2,834 2- 30B /ME -01 10/18/2011 24 542 5 462 2,839 2- 30B /ME -01 10/17/2011 24 545 6 464 2,843 2- 30B /ME -01 10/16/2011 24 547 7 466 2,776 • . Water Gas Report Oil Vol Vol Vol Gas Bore Date Hrs (bbls) (bbls) (mscfd) Lift Vol 2- 30B /ME -01 10/15/2011 24 550 7 468 2,726 2- 30B /ME -01 10/14/2011 24 552 8 471 2,768 2- 30B /ME -01 10/13/2011 24 555 8 473 2,835 2- 30B /ME -01 10/12/2011 24 557 9 475 2,845 2- 30B /ME -01 10/11/2011 24 559 9 477 2,840 2- 30B /ME -01 10/10/2011 24 562 10 479 2,827 2- 30B /ME -01 10/9/2011 24 564 11 481 2,836 2- 30B /ME -01 10/8/2011 24 567 11 483 2,831 2- 30B /ME -01 10/7/2011 24 569 12 486 2,836 2- 30B /ME -01 10/6/2011 24 572 12 488 2,850 2- 30B /ME -01 10/5/2011 24 574 13 490 2,847 2- 30B /ME -01 10/4/2011 24 576 13 492 2,842 2- 30B /ME -01 10/3/2011 24 579 14 494 2,853 2- 30B /ME -01 10/2/2011 24 581 14 496 2,852 2- 30B /ME -01 10/1/2011 24 584 14 498 2,892 2- 30B /ME -01 9/30/2011 24 560 13 477 2,920 2- 30B /ME -01 9/29/2011 24 560 13 477 2,927 2- 30B /ME -01 9/28/2011 24 560 13 477 2,923 2- 30B /ME -01 9/27/2011 24 566 13 483 2,943 2- 30B /ME -01 9/26/2011 24 573 13 489 2,940 2- 30B /ME -01 9/25/2011 24 579 13 496 2,933 2- 30B /ME -01 9/24/2011 24 585 13 502 2,938 2- 30B /ME -01 9/23/2011 24 591 13 508 2,903 2- 30B /ME -01 9/22/2011 24 597 13 514 2,954 2- 30B /ME -01 9/21/2011 24 603 13 520 2,926 2- 30B /ME -01 9/20/2011 24 609 13 526 2,913 2- 30B /ME -01 9/19/2011 24 615 13 532 2,961 2- 30B /ME -01 9/18/2011 24 621 13 538 2,932 2- 30B /ME -01 9/17/2011 24 627 13 544 2,934 2- 30B /ME -01 9/16/2011 24 627 11 542 2,972 2- 30B /ME -01 9/15/2011 24 627 9 541 2,964 2- 30B /ME -01 9/14/2011 24 627 7 539 2,969 2- 30B /ME -01 9/13/2011 24 626 5 538 3,025 2- 30B /ME -01 9/12/2011 24 626 2 536 3,008 2- 30B /ME -01 9/11/2011 24 626 2 534 2,931 2- 30B /ME -01 9/10/2011 24 630 2 538 2,965 2- 30B /ME -01 9/9/2011 24 633 2 541 2,970 2- 30B /ME -01 9/8/2011 24 637 2 544 2,994 2- 30B /ME -01 9/7/2011 24 641 2 547 2,968 2- 30B /ME -01 9/6/2011 24 645 2 551 2,993 1 2- 30B /ME -01 9/5/2011 24 649 2 554 2,988 2- 30B /ME -01 9/4/2011 24 653 2 557 3,021 2- 30B /ME -01 9/3/2011 24 657 2 561 3,042 2- 30B /ME -01 9/2/2011 24 661 2 564 3,031 2- 30B /ME -01 9/1/2011 24 665 2 567 3,151 2- 30B /ME -01 8/31/2011 24 708 4 603 2,999 2- 30B /ME -01 8/30/2011 24 708 4 603 3,001 2- 30B /ME -01 8/29/2011 24 708 4 603 3,005 • • f ', f Water Gas Report Oil Vol Vol Vol Gas Bore Date Hrs (bbls) (bbls) (mscfd) Lift Vol 2- 30B /ME -01 8/28/2011 24 708 4 603 3,008 2- 30B /ME -01 8/27/2011 24 708 4 603 2,987 2- 30B /ME -01 8/26/2011 24 708 4 603 3,030 2- 30B /ME -01 8/25/2011 24 708 4 603 3,020 2- 30B /ME -01 8/24/2011 24 708 4 603 3,027 2- 30B /ME -01 8/23/2011 24 708 4 603 3,006 2- 30B /ME -01 8/22/2011 24 708 4 603 3,000 2- 30B /ME -01 8/21/2011 24 708 4 603 2,990 2- 30B /ME -01 8/20/2011 24 707 4 586 3,096 2- 30B /ME -01 8/19/2011 24 706 4 569 3,098 2- 30B /ME -01 8/18/2011 24 705 4 551 3,079 2- 30B /ME -01 8/17/2011 24 704 5 534 3,080 2- 30B /ME -01 8/16/2011 24 703 5 516 3,116 2- 30B /ME -01 8/15/2011 24 702 5 499 3,148 2- 30B /ME -01 8/14/2011 24 701 5 482 3,132 2- 30B /ME -01 8/13/2011 24 700 6 464 3,117 2- 30B /ME -01 8/12/2011 24 700 6 447 3,020 2- 30B /ME -01 8/11/2011 24 699 6 430 2,988 2- 30B /ME -01 8/10/2011 24 698 6 412 3,060 2- 30B /ME -01 8/9/2011 24 697 7 395 3,053 2- 30B /ME -01 8/8/2011 24 696 7 377 2,960 2- 30B /ME -01 8/7/2011 24 695 7 360 2,934 2- 30B /ME -01 8/6/2011 24 718 6 353 2,864 2- 30B /ME -01 8/5/2011 24 740 5 345 2,953 2- 30B /ME -01 8/4/2011 24 763 5 338 2,988 2- 30B /ME -01 8/3/2011 24 785 5 331 3,024 2- 30B /ME -01 8/2/2011 24 808 4 324 2,953 2- 30B /ME -01 8/1/2011 24 831 4 316 2,971 2- 30B /ME -01 7/31/2011 24 989 2 265 2,942 2- 30B /ME -01 7/30/2011 24 989 2 265 2,908 2- 30B /ME -01 7/29/2011 24 989 2 265 2,870 2- 30B /ME -01 7/28/2011 24 989 2 265 2,939 2- 30B /ME -01 7/27/2011 24 989 2 265 2,947 2- 30B /ME -01 7/26/2011 24 989 2 265 2,932 2- 30B /ME -01 7/25/2011 24 989 2 265 2,960 2- 30B /ME -01 7/24/2011 24 986 3 273 2,895 2- 30B /ME -01 7/23/2011 24 984 3 280 2,857 2- 30B /ME -01 7/22/2011 24 981 3 287 2,843 2- 30B /ME -01 7/21/2011 24 979 3 294 2,823 2- 30B /ME -01 7/20/2011 24 977 3 302 2,801 2- 30B /ME -01 7/19/2011 24 974 3 309 2,731 2- 30B /ME -01 7/18/2011 16 646 2 210 2,097 2- 30B /ME -01 7/17/2011 0 0 0 0 0 2- 30B /ME -01 7/16/2011 1 57 0 20 437 2- 30B /ME -01 7/15/2011 24 964 4 338 2,887 2- 30B /ME -01 7/14/2011 24 962 4 346 2,834 2- 30B /ME -01 7/13/2011 24 959 4 353 2,835 2- 30B /ME -01 7/12/2011 24 957 4 360 2,808 • • Water Gas Report Oil Vol Vol Vol Gas Bore Date Hrs (bbls) (bbls) (mscfd) Lift Vol 2- 30B /ME -01 7/11/2011 24 954 5 367 2,724 2- 30B /ME -01 7/10/2011 24 952 5 375 2,699 2- 30B /ME -01 7/9/2011 24 949 5 382 3,002 2- 30B /ME -01 7/8/2011 24 940 5 386 2,771 2- 30B /ME -01 7/7/2011 20 789 5 331 2,308 2- 30B /ME -01 7/6/2011 0 0 0 0 0 2- 30B /ME -01 7/5/2011 0 0 0 0 0 2- 30B /ME -01 7/4/2011 0 0 0 0 0 2- 30B /ME -01 7/3/2011 0 0 0 0 0 2- 30B /ME -01 7/2/2011 0 0 0 0 0 2- 30B /ME -01 7/1/2011 0 0 0 0 0 2- 30B /ME -01 6/30/2011 0 0 0 0 0 2- 30B /ME -01 6/29/2011 0 0 0 0 0 2- 30B /ME -01 6/28/2011 0 0 0 0 0 2- 30B /ME -01 6/27/2011 0 0 0 0 0 2- 30B /ME -01 6/26/2011 0 0 0 0 0 2- 30B /ME -01 6/25/2011 0 0 0 0 0 2- 30B /ME -01 6/24/2011 0 0 0 0 0 2- 30B /ME -01 6/23/2011 0 0 0 0 0 2- 30B /ME -01 6/22/2011 0 0 0 0 0 2- 30B /ME -01 6/21/2011 0 0 0 0 0 2- 30B /ME -01 6/20/2011 0 0 0 0 0 2- 30B /ME -01 6/19/2011 0 0 0 0 0 2- 30B /ME -01 6/18/2011 0 0 0 0 0 2- 30B /ME -01 6/17/2011 0 0 0 0 0 2- 30B /ME -01 6/16/2011 0 0 0 0 0 2- 30B /ME -01 6/15/2011 0 0 0 0 0 2- 30B /ME -01 6/14/2011 0 0 0 0 0 2- 30B /ME -01 6/13/2011 0 0 0 0 0 2- 30B /ME -01 6/12/2011 0 0 0 0 0 2- 30B /ME -01 6/11/2011 0 0 0 0 0 2- 30B /ME -01 6/10/2011 0 0 0 0 0 2- 30B /ME -01 6/9/2011 0 0 0 0 0 2- 30B /ME -01 6/8/2011 0 0 0 0 0 2- 30B /ME -01 6/7/2011 0 0 0 0 0 2- 30B /ME -01 6/6/2011 0 0 0 0 0 2- 30B /ME -01 6/5/2011 0 0 0 0 0 2- 30B /ME -01 6/4/2011 0 0 0 0 0 2- 30B /ME -01 6/3/2011 0 0 0 0 0 2- 30B /ME -01 6/2/2011 0 0 0 0 0 2- 30B /ME -01 6/1/2011 0 0 0 0 0 2- 30B /ME -01 5/31/2011 19 544 0 63 2,742 2- 30B /ME -01 5/30/2011 24 700 0 81 3,279 2- 30B /ME -01 5/29/2011 24 700 0 81 3,277 2- 30B /ME -01 5/28/2011 24 700 0 81 3,304 2- 30B /ME -01 5/27/2011 24 700 0 81 3,293 2- 30B /ME -01 5/26/2011 24 700 0 81 3,264 2- 30B /ME -01 5/25/2011 24 700 0 81 3,296 • • Water Gas Report Oil Vol Vol Vol Gas Bore Date Hrs (bbls) (bbls) (mscfd) Lift Vol 2- 30B /ME -01 5/24/2011 24 700 0 81 3,287 2-30B/ME-01 5/23/2011 24 703 11 72 3,297 2- 30B /ME -01 5/22/2011 24 707 22 63 3,313 2- 30B /ME -01 5/21/2011 24 408 33 190 3,281 2- 30B /ME -01 5/20/2011 24 515 35 169 3,361 2- 30B /ME -01 5/19/2011 24 569 36 158 3,280 2- 30B /ME -01 5/18/2011 24 622 37 148 3,291 2- 30B /ME -01 5/17/2011 24 676 37 137 3,289 2- 30B /ME -01 5/16/2011 24 729 38 127 3,298 2-30B/ME-01 5/15/2011 24 731 40 128 3,351 2- 30B /ME -01 5/14/2011 24 733 42 130 3,348 2- 30B /ME -01 5/13/2011 24 735 44 131 3,343 2- 30B /ME -01 5/12/2011 24 737 45 133 3,346 2- 30B /ME -01 5/11/2011 24 739 47 134 3,385 2- 30B /ME -01 5/10/2011 24 736 46 142 3,405 2- 30B /ME -01 5/9/2011 24 733 45 149 3,341 2- 30B /ME -01 5/8/2011 24 730 44 157 3,381 2- 30B /ME -01 5/7/2011 24 727 43 164 3,295 2- 30B /ME -01 5/6/2011 24 724 42 172 3,278 2- 30B /ME -01 5/5/2011 24 721 41 179 3,316 2- 30B /ME -01 5/4/2011 24 717 41 187 3,293 2- 30B /ME -01 5/3/2011 24 709 40 193 3,339 2- 30B /ME -01 5/2/2011 24 711 40 202 3,291 2- 30B /ME -01 5/1/2011 24 708 39 209 3,261 2- 30B /ME -01 4/30/2011 24 677 28 285 3,236 2- 30B /ME -01 4/29/2011 24 677 28 285 3,263 2- 30B /ME -01 4/28/2011 24 677 28 285 3,350 2- 30B /ME -01 4/27/2011 24 677 28 285 3,309 2- 30B /ME -01 4/26/2011 24 677 28 285 3,283 2- 30B /ME -01 4/25/2011 24 677 28 285 3,172 2- 30B /ME -01 4/24/2011 24 677 28 285 3,204 2- 30B /ME -01 4/23/2011 24 677 28 285 3,354 2- 30B /ME -01 4/22/2011 24 677 28 285 3,228 2- 30B /ME -01 4/21/2011 24 677 28 285 3,159 2- 30B /ME -01 4/20/2011 24 690 29 285 3,170 2- 30B /ME -01 4/19/2011 24 704 30 285 3,104 2- 30B /ME -01 4/18/2011 24 717 31 285 3,179 2- 30B /ME -01 4/17/2011 24 730 32 285 3,159 2- 30B /ME -01 4/16/2011 24 744 33 286 3,087 2- 30B /ME -01 4/15/2011 24 997 42 254 3,171 2- 30B /ME -01 4/14/2011 24 1,251 52 223 3,088 2-30B/ME-01 4/13/2011 13 593 25 114 1,713 2- 30B /ME -01 4/12/2011 24 953 40 201 3,179 2- 30B /ME -01 4/11/2011 24 803 33 190 3,131 2- 30B /ME -01 4/10/2011 5 164 7 43 782 2- 30B /ME -01 4/9/2011 0 0 0 0 0 2-30B/ME-01 4/8/2011 8 234 10 76 1,349 2- 30B /ME -01 4/7/2011 24 642 26 232 2,912 • • Water Gas Report Oil Vol Vol Vol Gas Bore Date Hrs (bbls) (bbls) (mscfd) Lift Vol 2- 30B /ME -01 4/6/2011 24 601 24 243 2,916 2- 30B /ME -01 4/5/2011 24 561 22 253 2,957 2- 30B /ME -01 4/4/2011 24 520 20 264 2,921 2- 30B /ME -01 4/3/2011 24 480 18 274 2,902 2- 30B /ME -01 4/2/2011 24 439 16 285 2,926 2- 30B /ME -01 4/1/2011 24 399 16 295 2,962 2- 30B /ME -01 3/31/2011 24 358 13 306 2,744 2-30B/ME-01 3/30/2011 24 409 18 321 2,159 2- 30B /ME -01 3/29/2011 24 460 23 335 2,296 2- 30B /ME -01 3/28/2011 24 459 21 340 2,391 2- 30B /ME -01 3/27/2011 24 458 20 346 2,232 2- 30B /ME -01 3/26/2011 24 457 18 351 2,048 2- 30B /ME -01 3/25/2011 24 455 16 356 2,085 2- 30B /ME -01 3/24/2011 24 454 14 362 2,106 2- 30B /ME -01 3/23/2011 24 453 13 367 2,131 2-30B/ME-01 3/22/2011 24 452 11 373 2,182 2- 30B /ME -01 3/21/2011 24 451 9 378 2,161 2- 30B /ME -01 3/20/2011 24 463 11 380 2,205 2- 30B /ME -01 3/19/2011 24 474 12 383 2,216 2- 30B /ME -01 3/18/2011 24 486 14 385 2,227 2- 30B /ME -01 3/17/2011 24 497 15 387 2,241 2- 30B /ME -01 3/16/2011 24 509 17 390 2,245 2- 30B /ME -01 3/15/2011 24 521 19 392 2,241 2- 30B /ME -01 3/14/2011 24 532 20 394 2,283 2-30B/ME-01 3/13/2011 23 521 21 380 2,277 2- 30B /ME -01 3/12/2011 24 555 23 399 2,259 2- 30B /ME -01 3/11/2011 24 567 25 401 2,285 2- 30B /ME -01 3/10/2011 24 575 24 389 2,290 2- 30B /ME -01 3/9/2011 24 583 23 376 2,327 2- 30B /ME -01 3/8/2011 24 592 22 363 2,331 2- 30B /ME -01 3/7/2011 24 600 21 351 2,343 2- 30B /ME -01 3/6/2011 24 608 20 338 2,316 2- 30B /ME -01 3/5/2011 24 616 19 325 2,325 2- 30B /ME -01 3/4/2011 24 625 18 312 2,340 2- 30B /ME -01 3/3/2011 24 633 17 300 2,336 2- 30B /ME -01 3/2/2011 24 641 17 287 2,350 2- 30B /ME -01 3/1/2011 24 649 17 274 2,362 2- 30B /ME -01 2/28/2011 24 723 7 160 2,321 2- 30B /ME -01 2/27/2011 24 723 7 160 2,380 2- 30B /ME -01 2/26/2011 24 723 7 160 2,290 2- 30B /ME -01 2/25/2011 24 723 7 160 2,308 2- 30B /ME -01 2/24/2011 24 723 7 160 2,335 2- 30B /ME -01 2/23/2011 24 723 7 160 2,361 2- 30B /ME -01 2/22/2011 24 723 7 160 2,390 2- 30B /ME -01 2/21/2011 24 723 7 160 2,384 2- 30B /ME -01 2/20/2011 24 723 7 160 2,373 2- 30B /ME -01 2/19/2011 24 734 7 233 2,378 2- 30B /ME -01 2/18/2011 24 744 6 307 2,377 • • Water Gas Report Oil Vol Vol Vol Gas Bore Date Hrs (bbls) (bbls) (mscfd) Lift Vol 2- 30B /ME -01 2/17/2011 24 754 6 380 2,398 2- 30B /ME -01 2/16/2011 24 764 5 454 2,385 2- 30B /ME -01 2/15/2011 24 774 5 527 2,370 2- 30B /ME -01 2/14/2011 24 784 4 600 2,349 2- 30B /ME -01 2/13/2011 24 794 4 674 2,265 2- 30B /ME -01 2/12/2011 24 785 4 674 2,272 2- 30B /ME -01 2/11/2011 24 775 4 675 2,302 2- 30B /ME -01 2/10/2011 24 765 4 675 2,222 2- 30B /ME -01 2/9/2011 24 777 4 647 2,193 2- 30B /ME -01 2/8/2011 24 790 4 619 2,225 2- 30B /ME -01 2/7/2011 24 802 4 590 2,259 2- 30B /ME -01 2/6/2011 24 814 4 562 2,230 2- 30B /ME -01 2/5/2011 24 826 4 534 2,202 2- 30B /ME -01 2/4/2011 24 838 4 506 2,224 2- 30B /ME -01 2/3/2011 24 850 4 477 2,161 2- 30B /ME -01 2/2/2011 24 862 5 449 2,280 2- 30B /ME -01 2/1/2011 24 874 5 421 2,310 2- 30B /ME -01 1/31/2011 24 959 4 223 2,327 2- 30B /ME -01 1/30/2011 24 959 4 223 2,302 2- 30B /ME -01 1/29/2011 24 959 4 223 2,305 2- 30B /ME -01 1/28/2011 24 959 4 223 2,331 2- 30B /ME -01 1/27/2011 24 959 4 223 2,384 2- 30B /ME -01 1/26/2011 24 959 4 223 2,389 2- 30B /ME -01 1/25/2011 24 959 4 223 2,354 2- 30B /ME -01 1/24/2011 24 962 6 240 2,338 2- 30B /ME -01 1/23/2011 24 964 8 257 2,310 2-30B/ME-01 1/22/2011 24 967 11 273 2,388 2- 30B /ME -01 1/21/2011 24 969 13 290 2,372 2- 30B /ME -01 1/20/2011 24 972 15 307 2,371 2- 30B /ME -01 1/19/2011 24 974 18 324 2,367 2- 30B /ME -01 1/18/2011 24 976 20 340 2,322 2- 30B /ME -01 1/17/2011 9 369 8 131 966 2- 30B /ME -01 1/16/2011 0 0 0 0 0 2- 30B /ME -01 1/15/2011 1 3 0 1 664 2- 30B /ME -01 1/14/2011 24 1,012 24 377 2,629 2-30B/ME-01 1/13/2011 16 700 17 265 1,706 2- 30B /ME -01 1/12/2011 0 0 0 0 0 2- 30B /ME -01 1/11/2011 0 0 0 0 0 2- 30B /ME -01 1/10/2011 0 0 0 0 0 2- 30B /ME -01 1/9/2011 0 0 0 0 0 2-30B/ME-01 13 585 17 237 2,112 2- 30B /ME -01 1/7/2011 24 1,074 32 440 2,368 2- 30B /ME -01 1/6/2011 24 1,083 33 449 2,360 2- 30B /ME -01 1/5/2011 24 1,092 34 458 2,352 2- 30B /ME -01 1/4/2011 24 1,100 35 467 2,317 2-30B/ME-01 1/3/2011 24 1,109 36 476 2,346 2- 30B /ME -01 1/2/2011 24 1,118 37 485 2,336 2- 30B /ME -01 1/1/2011 24 1,127 40 494 2,345 • ,;,.:z, • • • Water Gas Report Oil Vol Vol Vol Gas Bore Date Hrs (bbls) (bbls) (mscfd) Lift Vol 2- 30B/ME -01 12/31/2010 24 1,154 42 522 2,381 2- 30B /ME -01 12/30/2010 24 1,154 42 522 2,375 2- 30B /ME -01 12/29/2010 24 1,154 42 522 2,356 2- 30B /ME -01 12/28/2010 13 594 23 259 1,877 2- 30B /ME -01 12/27/2010 24 1,114 45 467 2,265 2-30B/ME-01 12/26/2010 7 326 14 131 438 2-30B/ME-01 12/25/2010 11 484 22 186 1,304 2- 30B /ME -01 12/24/2010 24 1,053 50 386 2,362 2- 30B /ME -01 12/23/2010 24 1,033 52 359 2,364 2-30B/ME-01 12/22/2010 24 1,013 54 331 2,314 2- 30B /ME -01 12/21/2010 24 993 55 304 2,288 2- 30B /ME -01 12/20/2010 24 973 57 277 2,282 2- 30B /ME -01 12/19/2010 24 953 59 250 2,313 2- 30B /ME -01 12/18/2010 24 933 60 223 2,185 2- 30B /ME -01 12/17/2010 4 169 9 57 374 2- 30B /ME -01 12/16/2010 0 0 0 0 0 2- 30B /ME -01 12/15/2010 0 0 0 0 0 2- 30B /ME -01 12/14/2010 0 0 0 0 0 2- 30B /ME -01 12/13/2010 17 568 6 465 1,760 2- 30B /ME -01 12/12/2010 21 600 6 482 1,843 2- 30B /ME -01 12/11/2010 24 568 6 445 2,109 2- 30B /ME -01 12/10/2010 24 460 5 347 2,110 2- 30B /ME -01 12/9/2010 24 352 4 249 2,137 2- 30B /ME -01 12/8/2010 24 360 5 238 2,153 2- 30B /ME -01 12/7/2010 24 367 7 227 2,185 2- 30B /ME -01 12/6/2010 24 374 8 216 2,186 2- 30B /ME -01 12/5/2010 24 381 10 205 2,167 2- 30B /ME -01 12/4/2010 24 388 11 194 2,189 2- 30B /ME -01 12/3/2010 24 396 13 183 2,186 2- 30B /ME -01 12/2/2010 24 403 15 172 2,180 2-30B/ME-01 12/1/2010 24 410 15 161 2,194 • • 1: Well Test Data Total Form Gas Fluid Oil Water Gas Gas Lift Rate Rate Rate Rate Lift Press Well Bore Run Date Hrs (bpd) (bpd) (bpd) (mscfd) (mscfd) (psi) Chk 2- 30B/ME -01 11/28/2011 4 730 720 10 148 3,427 1,155 176 2- 30B /ME -01 11/24/2011 4 753 738 15 127 3,414 1,151 176 2-30B/ME-01 11/15/2011 4 651 543 107 451 3,463 1,140 176 2- 30B /ME -01 10/28/2011 4 618 614 5 523 3,274 1,159 176 2- 30B /ME -01 10/18/2011 4 548 542 5 462 3,129 1,255 176 2-30B/ME-01 9/30/2011 4 599 584 15 498 3,162 1,234 176 2- 30B /ME -01 9/27/2011 4 573 560 13 477 3,189 1,218 176 2- 30B /ME -01 9/17/2011 4 640 627 13 544 3,186 1,166 176 2- 30B /ME -01 9/11/2011 4 627 626 2 534 3,267 1,140 176 2- 30B /ME -01 8/21/2011 4 711 708 4 603 3,261 1,083 176 2- 30B /ME -01 8/6/2011 4 702 695 7 360 3,265 1,046 176 2- 30B /ME -01 7/25/2011 4 991 989 2 265 3,120 1,023 176 2-30B/ME-01 7/11/2011 4 949 944 5 397 3,173 1,076 176 2- 30B /ME -01 5/24/2011 4 700 700 0 81 3,419 1,104 176 2- 30B /ME -01 5/22/2011 4 729 707 22 63 3,440 1,110 176 2- 30B /ME -01 5/22/2011 4 442 408 33 190 3,381 1,098 176 2- 30B /ME -01 5/15/2011 4 767 729 38 127 3,515 1,118 176 2- 30B /ME -01 5/11/2011 4 786 739 47 134 3,479 1,118 176 2- 30B /ME -01 4/20/2011 4 705 677 28 285 3,303 1,080 176 2- 30B /ME -01 4/16/2011 4 776 744 33 286 3,364 1,088 176 2- 30B /ME -01 4/14/2011 4 1,303 1,251 52 223 3,354 1,144 176 2- 30B /ME -01 4/11/2011 4 837 803 33 190 3,373 1,292 176 2- 30B /ME -01 3/31/2011 4 371 358 13 306 3,161 1,417 176 2- 30B /ME -01 3/29/2011 4 483 460 23 335 2,383 1,297 176 2- 30B /ME -01 3/21/2011 4 460 451 9 378 2,403 1,253 176 2- 30B /ME -01 3/11/2011 4 592 567 25 401 2,474 1,169 176 2- 30B /ME -01 2/20/2011 4 731 723 7 160 2,573 1,017 176 2- 30B /ME -01 2/13/2011 4 798 794 4 674 2,593 979 176 2- 30B /ME -01 2/10/2011 4 769 765 4 675 2,539 966 176 2- 30B /ME -01 1/24/2011 4 963 959 4 223 2,565 963 176 2- 30B /ME -01 1/18/2011 4 996 976 20 340 2,601 989 176 2-30B/ME-01 12/28/2010 4 1,195 1,154 42 522 2,476 1,098 176 2- 30B /ME -01 12/18/2010 4 993 933 60 223 2,498 1,108 176 2- 30B /ME -01 12/13/2010 4 791 783 8 641 2,225 914 176 2- 30B /ME -01 12/9/2010 8 356 352 4 249 2,327 951 176 • • / 7 by David J. Szabo RECEIVED Head of Reservoir Management JUN 2 1 2 010 Alaska Resource Team � BP Exploration (Alaska) Inc. Alaska Oil & Gas Cans. Commission P.O. Boxt196612 Boulevard Anchorage Anchorage, Alaska 99519 -6612 Q$ (907) 561 -5111 June 15, 2010 Phone: (907) 564 -4788 Fax: (907) 564 -4440 Email SzaboDJ@bp.com Mr. Kevin R. Banks, Director Web: www.bp.com Division of Oil and Gas 550 West 7 Avenue, Suite 1100 Anchorage Alaska 99501 Re: Request for Extension of Accounting Code for Tract Operations, 2- 30B /ME -01 ADL 034633 Duck Island Unit (DIU) Tract 13 Dear Mr. Banks, BP Exploration (Alaska) Inc. (BPXA), as Duck Island Unit Operator, completed the authorized well 2- 30B /ME -01 on March 17, 2009 and performed the first production test on April 6, 2009. BPXA has since determined that the Sag/Ivishak Undefined Oil Pool (SIUOP) does not have sufficient reserves to justify the drilling of additional wells to the pool (see attachment 1). BPXA concluded that primary depletion alone would cause oil production well 2- 30B /ME -01 to exceed gas -oil ratio limitations of 20 AAC 25.240(a). On March 4, 2010 BPXA applied to the AOGCC for a permanent waiver of those limitations (see attachment 2). On May 28, 2010, the AOGCC issued Conservation Order 630 authorizing a permanent waiver to exceed the gas -oil ratio limitations of 20 AAC 25.240(a) for oil production well 2- 30B /ME -01 (attachment 3). BPXA requests a three (3) year extension to the accounting code DIO2, due to expire July 1, 2010, in order to collect additional reservoir performance data to further refine the extent of the accumulation. BPXA's current plans include gathering reservoir pressure data during a planned DIU facility shut down scheduled for early September 2010. If you have any concerns or questions regarding these submittals or subsequent well operations, please contact David Lenig at 907 - 564 -5301 or R. L. Skillern at 907 -564- 5567. Sincerely, .(U David J. Szab Enclosures 1 • Mr. Kevin Banks June 15, 2010 Page 2 cc: Ms. Cammy Taylor, Division of OiI and Gas Ms. Temple Davidson, Division of OiI and Gas r. Dan Seamount , Alaska Oil and Gas Conservation Commission Ms. Judy Buono, BPXA Mr. R.L. Skillern, BPXA Ms. Amy Frankenburg, BPXA Mr. John Garing, BPXA • • Mr. Kevin Banks June 15, 2010 Page 3 Attachment 1 Primary Production Ultimate Recovery Question and Finding What ultimate recovery can be expected with primary production of the Minke reservoir? — An ultimate recovery of 380,000 stbo or 12% of OOIP can be expected Method Decline Curve Analysis & Material Balance (Tamer method) Application to Minke When fitting the well test data with a hyperbolic decline curve, the estimated ultimate recovery for Well 2- 30B /ME -01 is 378,000 stbo. Based on an OOIP of 3.24 mmstbo, the estimated recovery factor is 11.7 %. Comparing the results from decline curve analysis to the estimated recovery factor calculated from material balance (Tamer method), the results are very favorable to one another. f o000 Qi = 785 stbopd Di = 26% per year N =0.5 woo 2 ,00 ,o p � 0 cS V V Z M g 8 it 1 • Well Test Oil Rate -- DCA Forecast (well tests) • • Mr. Kevin Banks June 15, 2010 Page 4 Water Flood Ultimate Recovery Question and Finding What ultimate recovery can be expected by waterflooding the Minke reservoir? — An ultimate WF recovery of 18.7 — 22.3% can be expected with 75% confidence Method Guthrie- Greenberger From: The Reservoir Engineering Aspects of Waterflooding by Forrest F. Craig. Jr. pg 83 "This method estimates oil recovery by water drive using an empirically determined equation based on reservoir rock and fluid properties. 73 sand -stone reservoirs, with actual production data were studied. The reservoirs had water drive or solution gas drive combined with water drive. In this method, oil recovery is related to permeability, porosity, oil viscosity, formation thickness, connate water saturation, depth, oil reservoir volume factor, area and well spacing. The correlation has been shown to fit so well that 50% of the time the recovery factor was within 6.2 % of actual reported value, and 75% of the time it was within 9 %. " RF = 0.2719 log k + 0.25569 Sw — 0.1355 log µ„ — 1.5380 - 0.0003488 h + 0.11403 Application to Minke Minke is analogous to the reservoirs used to determine the empirical equation as it is a sand -stone reservoir which produces under solution gas drive, with the prospect of water drive. The properties in the table below were determined from the well log and PVT data and were used in the equation stated above to calculate recovery factor. Properties Sag B Sag A Permeability k (md) 37 7 Connate water saturation Sw 0.31 0.39 Oil viscosity p. (cp) 1.1 1.1 Porosity fp 0.25 0.2 Formation thickness h (ft) 41 14 Calculated RF 21.5% 12.5% The static model has an OOIP of 2.9 mmstbo for the Sag B and 0.34 mmstbo for the Sag A, which calculates an ultimate WF recovery for the Minke reservoir of 20.5 %. Using the information from above to estimate uncertainty on this estimated recovery factor shows there is a 75% chance that recovery factor will fall within the range of 18.7% — 22.3 %. • • Mr. Kevin Banks June 15, 2010 Phone: (907) 564 -4788 Page 5 Fax: (907) 564 -4440 Email SzaboDJ @bp.com Web: www.bp.com Attachment 2 March 4, 2010 Mr. Daniel Seamount Alaska Oil and Gas Conservation Commission Phone: (907) 564 -4788 333 W. 7th Avenue, Suite 100 Fax: (907) 564 -4440 Anchorage, AK 99501 Email SzaboDJ @bp.com Web: www.bp.com RE: Request for permanent waiver of the gas oil ratio limitations for Well 2- 30B /ME -01 Dear Mr. Seamount: In accordance with 20 AAC 25.240.B.3, BP as Operator of the Duck Island Unit and sole Working Interest Owner of lease ADL 34633 (Tract 13), requested and received temporary waiver of the gas - oil ratio limitations for Well 2- 30B /ME -01 through March 31, 2010, with the intent of acquiring reservoir performance data (gas, oil and water trends) and pressure data to help determine the potential for additional reservoir development. Since first production on April 6, 2009, BP has performed thirty four well tests and two pressure build -up analyses on Well 2- 30B /ME -01. Using the aforementioned data as inputs for material balance calculation, the original oil in place (OOIP) for the SAG was estimated to be on the lower end of the pre -drill range. Based on the lower estimate of OOIP, an estimate of incremental waterflood recovery using analytical and analogue methods, and an estimate of drilling and completion costs, BP has determined that drilling an injection well is not competitive. BP hereby recommends continued depletion of the volume being drained by Well 2- 30B /ME -01 under solution gas drive mechanism without any additional development in the Minke accumulation. In order to produce the well in excess of 100% of original solution gas -oil ratio, a permanent waiver of the gas - oil ratio limitation is requested. In accordance with 20 AAC 25.240.C, BP as Operator of the Duck Island Unit and sole Working Interest Owner of lease ADL 34633 (Tract 13), hereby requests permanent waiver of the gas -oil ratio limitations for Well 2- 30B /ME -01. To allow sufficient time for the public hearing process, BP also requests extension of the temporary waiver of the gas -oil ratio limitations for Well 2- 30B /ME -01 through April 30, 2010. Should you have any questions, please contact Frank Paskvan at (907) 564 -5749. Sincerely, David J. Szabo r • Mr. Kevin Banks June 15, 2010 Page 6 Attachment 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF BP Exploration ) Docket Number: CO -10 -07 (Alaska) Inc. for an order granting a ) Conservation Order No. 630 waiver to the gas -oil ratio limitations of ) 20 AAC 25.240(a) for the 2- 30B/ME -01 ) Endicott Field oil production well. ) Duck Island Unit Sagilvishak Undefined Oil Pool ) North Slope Borough, Alaska ) ) May 28, 2010 IT APPEARING THAT: 1. By application dated March 4, 2010, BP Exploration (Alaska) Inc. (BPXA) requested a conservation order from the Alaska Oil and Gas Conservation Commission (Commission) granting a waiver to the gas -oil ratio limitations of 20 AAC 25.240(a) for the 2- 30B/ME -01 well in the Sag/lvishak Undefined Oil Pool of the Duck Island Unit. 2. On March 29, 2010, pursuant to 20 AAC 25.540, the Commission published in the Anchorage Daily News notice of opportunity for public hearing on May 4, 2010. 3. On March 17, 2010. BPXA submitted supplemental information to the Commission and requested that the information be held confidential pursuant to AS 38.05.035(a)(8)(c) and 11 AAC 82.810(a). 4. The Commission received no comments or requests to hold the hearing, so the hearing was vacated April 19, 2010. FINDINGS: 1. Well 2- 30B /ME-01 was drilled by BPXA to test a potential oil accumulation that is outside of the boundaries of any existing pool in the Duck Island Unit. The Commission has named this accumulation the Sag/Ivishak Undefined Oil Pool ( SIUOP). Production from the well and pool began on April 16, 2009. 2. On August 24, 2009, in accordance with 20 AAC 25.240(b)(3), BPXA requested a waiver of the gas -oil ratio limitations in 20 AAC 25.240(a) to allow for continued acquisition of production data necessary to develop a permanent reservoir management plan for the SIUOP. On September 9, 2009, the Commission granted a temporary waiver until March 31, 2010. On March 25, 2010, the Commission extended the temporary waiver through May 31, 2010, to • • Mr. Kevin Banks June 15, 2010 Page 7 Conservation Order 630 May 28, 2010 Page 2of4 allow sufficient time for the Commission to complete the public process required by 20 AAC25240(c) before rendering this decision. 3. BPXA has determined that the SIUOP does not have sufficient reserves to justify the drilling of additional wills to the pool. BPXA will continue to produce the pool by primary depletion using only well 2- 30B1ME -01. BPXA contends that � pear!' depletion alone will cause 2-30B/ME -01 to exceed the gas -oil ratio limitations of 20 AAC 252a), so a permanent wain of those limitations is required.. 4. Commission review of public records indicates that cumulative production for well 2- 30BIME -0l through April 30, 2010 was approximately 287,000 barrels of oil. Hyperbolic decline curve analysis of public production data indicates that under primary depletion the ultimate recovery for the well is approximately 400,000 barrels of oil, assuming an economic limit of 100 barrels of oil per day. 5. Water injection support generally increases ultimate recovery by 50 to 100 percent over primary depletion alone, although any increase is highly dependant urn reservoir rock and fluid properties. Adding an offset injection well to support 2-30B/ME -01 could increase ultimate recovery from the SIUOP by about 200,000 to 400,000 barrels of oil. However, this relatively modest increase in recoverable reserves does not justify the expense of drilling an offset injection well. our — — — — - -- - l R ...._ „t 434•B>awe .else 1 7443100.e 4471411e111 i r q,4,ns11 '. � sarnr 9estaesw 1 10in P Pet 2108 Awns ,1141/0414$ I IMO Amarrec001 14007011 deli .4041VMM _ y aw 04$/0 err 8 i - - 10 I — - -- -- -- --_ —_ .— -' W -- 1, 6. Commission senior staff reviewed the pool rules for other North Slope oil pools to estimate the additional recovery expected from well 2-3081ME -01 if an of et injection well were added to the reservoir. • . Mr. Kevin Banks June 15, 2010 Page 8 Conservation Order 630 May 28, 2010 Page 3of4 7. The Commission's authority to grant BPXA's requested confidentiality for the information submitted March 17, 2010 lies under AS 31.05.035(d) and 20 AAC 25337(b). CONCLUSIONS: 1. Regulation 20 AAC 25.240(c) provides the Commission authority to grant exceptions to the gas -oil ratio limitations of 20 AAC 25.240(a). 2_ Continued oil production from well 2- 30B44E -01 under primary depletion alone will exceed the gas -oil ratio limitations of 20 AAC 25/40(a). 1 The relatively modest increase of 200,000 to 400,000 barrels of oil does not justify the expense of drilling an offset injection well. 4, BPXA's request for confidentiality for the information submitted on March 17, 2010, is proper as this information not normally required by the statutes or regulations. NOW THEREFORE IT IS ORDERED that the gas -oil ratio limitations of 20 AAC 25.240(a) be waived for oil production well 2- 3081ME -01. BPXA's request to hold confidential the infomation submitted March 17, 2010 is granted. DONE at Anchorage, Alaska and dated May 28, 2010. Daniel T. Seamoynt, .1 ., Ccmunissioner, Chair Al - Oil and tnservation Commission dr/ "Lt.( t a n, Ctwnmi taller ( I a Gas Ct Commission • ‘„,`,1" fi "" Cathy , Commissioner Alaska Or and Gas Conservation Commission bp • • David J. Szabo Head of Resource Management BP Exploration Boulevard ns ( Alska) Inc. 9 900 East Benson B Alaska Consolidated Team (ACT) PO Box 196612 Anchorage, AK 99519 -6612 (907) 564 -5111 January 18, 2010 Phone: (907) 564 -4788 Fax: (907) 564 -4440 Email SzaboDJ @bp.com Web: www.bp.com RECEIVED JAN 2 0 2010 Alaska O & an CenL. Commission Mr. Kevin Banks, Acting Director Antipope Division of Oil & Gas Alaska Department of Natural Resources 550 W. 7 Avenue, Suite 800 Anchorage, Alaska 99501 3560 Re: January 13, 2010, Presentation of 2- 30B /ME -01 Results and Summary Dear Mr. Banks: On January 13, 2010, BP Exploration (Alaska) Inc., ( "BP ") made a technical presentation of the results and summary of the 2- 30B /ME -01 well to the Division of Oil and Gas ( "Division "). Pursuant to the request of the Division, please find enclosed a copy of the material presented by BP at the presentation. In accordance with 11AAC82.810 and AS38.05.035, BP requests that the Division keep this information confidential. Sincerely, David J. Szabo Attachment cc: ■ Seamount — AOGCC CI N t-S �w u�' 0 David Roby — AOGCC 11 1r t l0 b J o te 4, y`te .t14 It. IF4,40 bp ! • David J. Szabo 0 BP Head of Resource Management 900 E Eastt r Be n l Benson Boulevard Alaska Consolidated Team (ACT) PO Box 196612 Anchorage, AK 99519 -6612 (907) 564 -5111 December 15, 2009 Phone: (907) 564 -4788 Fax: (907) 564 -4440 Email SzaboDJ @bp.com Mr. Kevin Banks, Acting Director Web: www.bp.com Division of Oil & Gas State of Alaska, Dept. of Natural Resources RECEIVED 550 West 7 Avenue, Suite 800 Anchorage, AK 99501 -3560 Jr ?009 Mr. John Norman Alaska Oil Gas Cons. Commissions Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Arfcimr:pg Anchorage, AK 99501 RE: Summary Report of Well 2- 30B /ME -01 Testing and Production Gentlemen, As requested in the AOGCC's letter of January 22, 2009 and the DNR's letter of June 15, 2009 attached is a report of the rig spud, well tests and allocated production for the 2- 30B /ME -01 well. • The Drilling rig for the 2- 30B /ME -01 well was moved onto location on February 15, 2009 and released from location on March 17, 2009. • The well was perforated from 13810 to 13854 ft measured depth on April 4, 2009 in the Sag Formation. • Production testing of the well began on April 6, 2009. The well was shut -in for a fracture stimulation on April 8, 2009 and production testing recommenced on April 20, 2009. The well was shut -in from July 8 through August 3, 2009 for a pressure buildup test during a planned facility shutdown. Production testing resumed on August 4, 2009 and is currently ongoing. • A listing of the well tests and allocated daily production is in attachments A and B. Should you have any questions, please contact John Garing at (907) 564 -5167. Sincerely, David J. Szabo Enclosures cc: John Garing Endicott Files c9O7s"t 7 Attachment A - Protion Summary and Data since startup Test period Average Average Average Total Oil Total Total Gas Summary 2 -30B Daily Oil Water Gas Rate Production Water Production Rate Rate Production bbl bbl - mscf bbl bbl mscf Apr 6 - April 8 953.3 20.7 770.0 2860 62 2310 Apr 20 - July 7 1347.2 33.5 2570.6 106426 2644 203,081 Aug 4 - Nov. 30, 888.8 13.5 2467.6 105765 1609 293,648 2009 * Daily data available through 11 -30 -2009. Last well test on 11 -30. Production Data Water Gas Gas Lift Report Oil Rate Rate Rate Rate Bore Date Hrs , (bbls) (bbls) (mcfd) (mcfd) 2- 30B /ME -01 11/30/2009 24 620 _ 5 1,808 2,310 2- 30B /ME -01 11/29/2009 24 620 7 1,856 2,297 2- 30B /ME -01 11/28/2009 24 619 8 1,905 2,371 2- 30B /ME -01 11/27/2009 24 616 9 1,945 2,429 2- 30B /ME -01 11/26/2009 24 618 11 2,001 2,495 2- 30B /ME -01 11/25/2009 24 618 12 2,049 2,482 2- 30B /ME -01 11/24/2009 24 617 14 2,097 2,578 2- 30B /ME -01 11/23/2009 22 559 _ 14 1,943 2,585 2- 30B /ME -01 11/22/2009 24 617 16 2,194 2,538 2- 30B /ME -01 11/21/2009 24 616 18 2,242 2,508 2-30B/ME-01 11/20/2009 13 323 10 1,200 2,217 2- 30B /ME -01 11/19/2009 12 312 11 1,186 1,228 2- 30B /ME -01 11/18/2009 2 64 2 249 453 2-30B/ME-01 11/17/2009 10 254 10 1,006 1,186 2- 30B /ME -01 11/16/2009 24 614 25 2,483 2,492 2- 30B /ME -01 11/15/2009 20 515 22 2,122 1,029 2- 30B /ME -01 11/14/2009 24 613 28 2,579 0 2- 30B /ME -01 11/13/2009 24 613 29 2,628 0 2- 30B /ME -01 11/12/2009 24 613 31 2,676 0 2-30B/ME-01 11/11/2009 24 612 32 2,724 0 2- 30B /ME -01 11/10/2009 24 612 34 2,772 0 2-30B/ME-01 11/9/2009 24 621 32 2,763 1,241 2- 30B /ME -01 11/8/2009 24 _ 631 30 2,753 2,382 2- 30B /ME -01 11/7/2009 24 640 28 2,744 2,403 2- 30B /ME -01 11/6/2009 24 650 26 2,734 2,392 2- 30B /ME -01 11/5/2009 24 654 24 2,700 2,338 2- 30B /ME -01 11/4/2009 24 669 _ 23 2,715 2,357 2- 30B /ME -01 11/3/2009 24 679 21 2,706 2,364 2- 30B /ME -01 11/2/2009 24 688 19 2,696 2,392 2- 30B /ME -01 11/1/2009 25 727 18 2,799 2,339 2- 30B /ME -01 10/31/2009 24 736 10 , 2,649 2,469 2- 30B /ME -01 10/30/2009 24 736 10 2,649 2,604 2- 30B /ME -01 10/29/2009 21 657 9 2,362 0 2- 30B /ME -01 10/28/2009 24 736 10 2,649 215 2 Attachment A - Proction Summary and Data since startup. 2- 30B /ME -01 10/27/2009 24 740 9 2,583 1,558 2- 30B /ME -01 10/26/2009 24 744 8 2,517 2,360 2- 30B /ME -01 10/25/2009 24 747 8 2,451 2,321 2- 30B /ME -01 10/24/2009 24 751 7 2,384 2,394 2- 30B /ME -01 10/23/2009 24 722 6 2,351 2,845 2- 30B/ME -01 10/22/2009 23 656 5 2,196 2,859 2- 30B /ME -01 10/21/2009 24 663 4 2,285 2,965 2- 30B /ME -01 10/20/2009 24 634 3 2,252 2,000 2- 30B /ME -01 10/19/2009 24 666 8 2,376 0 2- 30B /ME -01 10/18/2009 24 699 13 2,499 0 2- 30B /ME -01 10/17/2009 24 732 19 2,623 0 2- 30B /ME -01 10/16/2009 24 764 24 2,746 0 2- 30B /ME -01 10/15/2009 24 731 23 2,648 0 2- 30B /ME -01 10/14/2009 24 739 21 2,651 0 2- 30B /ME -01 10/13/2009 24 748 20 2,655 0 2- 30B /ME -01 10/12/2009 24 756 19 2,658 0 2- 30B /ME -01 10/11/2009 24 764 18 2,661 0 2- 30B /ME -01 10/10/2009 24 772 17 2,665 0 2- 30B /ME -01 10/9/2009 24 780 15 2,668 0 2- 30B /ME -01 10/8/2009 24 788 14 2,672 0 2- 30B /ME -01 10/7/2009 24 796 13 2,675 0 2- 30B /ME -01 10/6/2009 24 804 12 2,679 0 2- 30B /ME -01 10/5/2009 24 812 10 2,682 0 2- 30B /ME -01 10/4/2009 24 820 9 2,686 0 2- 30B /ME -01 10/3/2009 24 829 _ 8 2,689 0 2- 30B /ME -01 10/2/2009 24 830 9 2,687 0 2- 30B /ME -01 10/1/2009 24 831 9 2,685 0 2- 30B /ME -01 9/30/2009 24 840 16 2,671 0 2- 30B /ME -01 9/29/2009 24 840 16 2,671 0 2- 30B /ME -01 9/28/2009 24 840 16 2,671 0 2- 30B /ME -01 9/27/2009 24 840 16 2,671 0 2- 30B /ME -01 9/26/2009 24 840 16 2,671 0 2- 30B /ME -01 9/25/2009 24 840 16 2,671 0 2- 30B /ME -01 9/24/2009 24 840 16 2,671 0 2- 30B /ME -01 9/23/2009 24 848 16 2,698 0 2- 30B /ME -01 9/22/2009 24 855 16 2,726 0 2- 30B /ME -01 9/21/2009 24 863 16 2,753 0 2- 30B /ME -01 9/20/2009 24 870 16 2,781 0 2- 30B /ME -01 9/19/2009 24 878 15 2,808 0 2- 30B /ME -01 9/18/2009 24 885 15 2,836 0 2- 30B /ME -01 9/17/2009 24 893 15 2,863 0 2- 30B /ME -01 9/16/2009 24 900 15 2,891 0 2- 30B /ME -01 9/15/2009 24 908 15 2,918 0 2- 30B /ME -01 9/14/2009 24 915 15 2,946 0 2- 30B /ME -01 9/13/2009 24 923 14 2,973 0 2- 30B /ME -01 9/12/2009 24 930 14 3,001 0 2- 30B /ME -01 9/11/2009 24 941 15 2,846 0 2- 30B /ME -01 9/10/2009 24 951 15 2,692 0 2- 30B /ME -01 9/9/2009 24 961 16 2,538 0 2- 30B /ME -01 9/8/2009 24 971 17 2,383 0 2- 30B /ME -01 9/7/2009 24 904 13 2,494 0 2- 30B /ME -01 9/6/2009 24 838 10 2,605 0 2- 30B /ME -01 9/5/2009 24 771 6 2,716 0 3 Attachment A - PrOction Summary and Data since startup 0 2- 30B /ME -01 9/4/2009 24 704 2 2,827 0 2- 30B /ME -01 9/3/2009 23 710 2 2,666 0 2- 30B /ME -01 9/2/2009 24 789 3 2,779 0 2- 30B /ME -01 9/1/2009 24 831 4 2,755 0 2- 30B /ME -01 8/31/2009 24 1,469 8 2,396 0 2- 30B /ME -01 8/30/2009 24 1,469 8 2,396 0 2- 30B /ME -01 8/29/2009 24 1,469 8 2,396 0 2- 30B /ME -01 8/28/2009 24 1,469 8 2,396 0 2- 30B/ME -01 8/27/2009 24 1,469 8 2,396 0 2- 30B /ME -01 8/26/2009 24 1,469 8 2,396 0 2- 30B /ME -01 8/25/2009 24 1,469 8 2,396 0 2- 30B /ME -01 8/24/2009 24 1,469 8 2,396 0 2- 30B /ME -01 8/23/2009 24 1,469 8 2,396 0 2- 30B /ME -01 8/22/2009 24 1,469 8 2,396 0 2- 30B /ME -01 8/21/2009 24 1,469 8 2,396 0 2- 30B /ME -01 8/20/2009 21 1,288 7 2,102 0 2- 30B /ME -01 8/19/2009 24 1,469 8 2,396 0 2- 30B /ME -01 8/18/2009 24 1,469 8 2,396 0 2- 30B /ME -01 8/17/2009 24 1,469 8 2,396 0 2- 30B /ME -01 8/16/2009 24 1,461 8 2,397 0 2- 30B /ME -01 8/15/2009 24 1,452 9 2,397 0 2-30B/ME-01 8/14/2009 22 1,331 9 2,211 0 2- 30B /ME -01 8/13/2009 22 1,324 10 2,212 0 2-30B/ME-01 8/12/2009 24 1,427 11 2,399 0 2- 30B/ME -01 8/11/2009 24 1,419 12 2,400 0 2- 30B /ME -01 8/10/2009 24 1,410 13 2,400 0 2-30B/ME-01 8/9/2009 24 1,402 13 2,401 0 2- 30B /ME -01 8/8/2009 24 1,394 14 2,402 0 2- 30B /ME -01 8/7/2009 24 1,385 15 2,402 0 2- 30B /ME -01 8/6/2009 24 1,377 15 2,403 0 2- 30B /ME -01 8/5/2009 24 1,349 15 2,368 0 2-30B/ME-01 8/4/2009 15 854 10 1,510 0 2- 30B /ME -01 8/3/2009 0 0 0 0 0 2- 30B /ME -01 8/2/2009 0 0 0 0 0 2- 30B /ME -01 8/1/2009 0 0 0 0 0 2- 30B /ME -01 7/31/2009 0 0 0 0 0 2- 30B /ME -01 7/30/2009 0 0 0 0 0 2- 30B /ME -01 7/29/2009 0 0 0 0 0 2- 30B /ME -01 7/28/2009 _ 0 0 0 0 0 2- 30B /ME -01 7/27/2009 0 0 0 0 0 2- 30B /ME -01 7/26/2009 0 0 0 0 0 2- 30B /ME -01 7/25/2009 0 0 0 0 0 2- 30B /ME -01 7/24/2009 0 0 0 0 0 2- 30B /ME -01 7/23/2009 0 0 0 0 0 2- 30B /ME -01 7/22/2009 0 0 0 0 0 � 2- 30B /ME -01 7/21/2009 0 0 0 0 0 2- 30B /ME -01 7/20/2009 0 0 0 0 0 2- 30B /ME -01 7/19/2009 0 0 0 0 0 2- 30B /ME -01 7/18/2009 0 0 0 0 0 2- 30B /ME -01 7/17/2009 0 0 0 0 0 2- 30B /ME -01 7/16/2009 0 0 0 0 0 2- 30B /ME -01 7/15/2009 0 0 0 0 0 2- 30B /ME -01 7/14/2009 0 0 0 0 0 4 Attachment A - Priktion Summary and Data since startup • 2- 30B /ME -01 7/13/2009 0 0 0 0 0 2- 30B /ME -01 7/12/2009 0 0 0 0 0 2- 30B /ME -01 7/11/2009 0_ 0 0 0 0 2- 30B /ME -01 7/10/2009 0 0 0 0 0 2- 30B /ME -01 7/9/2009 0 0 0 0 0 2- 30B /ME -01 7/8/2009 0 0 0 0 0 2-30B/ME-01 7/7/2009 14 596 26 1,401 0 2- 30B /ME -01 7/6/2009 24 1,034 44 2,428 0 2- 30B /ME -01 7/5/2009 24 1,034 44 2,428 0 2- 30B /ME -01 7/4/2009 24 1,034 44 2,428 0 2- 30B /ME -01 7/3/2009 24 1,012 43 2,377 0 2-30B/ME-01 7/2/2009 1 60 3 142 0 2 -30B /M E -01 7/1/2009 13 579 25 1,361 0 2- 30B /ME -01 6/30/2009 24 1,034 44 2,428 0 2- 30B /ME -01 6/29/2009 24 1,034 44 2,428 0 2- 30B /ME -01 6/28/2009 24 1,034 44 2,428 0 2- 30B /ME -01 6/27/2009 24 1,034 44 2,428 0 2- 30B /ME -01 6/26/2009 24 1,034 44 2,428 0 2- 30B /ME -01 6/25/2009 24 956 30 2,385 0 2- 30B /ME -01 6/24/2009 24 878 16 2,341 0 2- 30B /ME -01 6/23/2009 24 903 17 2,332 0 2- 30B /ME -01 6/22/2009 24 928 19 2,323 0 2- 30B /ME -01 6/21/2009 24 953 20 2,314 0 2- 30B /ME -01 6/20/2009 24 978 21 2,305 0 2- 30B /ME -01 6/19/2009 24 1,003 23 2,296 0 2- 30B /ME -01 6/18/2009 24 1,028 24 2,287 0 2- 30B /ME -01 6/17/2009 24 1,053 26 2,277 0 2- 30B /ME -01 6/16/2009 24 1,078 27 2,268 0 2 -30B /M E -01 6/15/2009 24 1,103 29 2,259 0 2- 30B /ME -01 6/14/2009 24 1,128 30 2,250 0 2- 30B /ME -01 6/13/2009 24 1,152 32 2,241 0 2- 30B /ME -01 6/12/2009 24 1,177 33 2,232 0 2- 30B /ME -01 6/11/2009 24 1,202 35 2,223 0 2-30B/ME-01 6/10/2009 24 1,160 34 2,189 0 2-30B/ME-01 6/9/2009 24 1,118 34 2,155 0 2- 30B /ME -01 6/8/2009 24 1,076 34 2,121 0 2- 30B /ME -01 6/7/2009 24 1,033 34 2,087 0 2- 30B /ME -01 6/6/2009 24 991 34 2,053 0 2- 30B /ME -01 6/5/2009 24 949 33 2,019 0 2- 30B /ME -01 6/4/2009 24 959 32 1,999 0 2- 30B /ME -01 6/3/2009 24 969 31 1,980 0 2- 30B /ME -01 6/2/2009 24 979 30 1,960 0 2- 30B /ME -01 6/1/2009 24 989 30 1,940 0 2-30B/ME-01 5/31/2009 24 1,020 25 1,881 0 2- 30B /ME -01 5/30/2009 24 1,020 25 1,881 0 2-30B/ME-01 5/29/2009 24 1,020 25 1,881 0 2- 30B /ME -01 5/28/2009 24 1,030 24 1,877 0 2- 30B /ME -01 5/27/2009 24 1,039 23 1,873 0 2- 30B /ME -01 5/26/2009 24 1,049 _ 22 1,868 0 2- 30B /ME -01 5/25/2009 24 1,059 21 1,864 0 2- 30B /ME -01 5/24/2009 24 1,069 20 1,860 0 2- 30B /ME -01 5/23/2009 24 1,079 20 1,856 0 2 -30B /M E -01 5/22/2009 24 1,089 19 1,852 0 5 Attachment A - Prl "tion Summary and Data since startup 2- 30B /ME -01 5/21/2009 24 1,099 18 1,848 0 2-30B/ME-01 5/20/2009 24 1,109 17 1,843 0 2-30B/ME-01 5/19/2009 24 1,118 16 1,839 0 2-30B/ME-01 5/18/2009 24 1,128 15 1,835 0 2-30B/ME-01 5/17/2009 24 1,124 15 1,910 0 2- 30B /ME -01 5/16/2009 24 1,119 14 1,986 0 2-30B/ME-01 5/15/2009 24 1,114 14 2,061 0 2-30B/ME-01 5/14/2009 24 1,103 14 2,124 0 2- 30B/ME -01 5/13/2009 24 1,104 14 2,211 0 2-30B/ME-01 5/12/2009 24 1,100 14 2,286 0 2- 30B /ME -01 5/11/2009 24 1,095 13 2,362 0 2- 30B /ME -01 5/10/2009 24 1,090 13 2,437 0 2- 30B /ME -01 5/9/2009 24 1,357 42 3,373 0 2- 30B /ME -01 5/8/2009 24 1,623 71 4,310 0 2- 30B /ME -01 5/7/2009 24 1,755 70 4,366 0 2- 30B /ME -01 5/6/2009 24 1,886 69 4,422 0 2- 30B /ME -01 5/5/2009 24 2,017 68 4,478 0 2- 30B /ME -01 5/4/2009 24 2,149 66 4,535 0 2- 30B /ME -01 5/3/2009 24 2,072 54 4,483 0 2- 30B /ME -01 5/2/2009 24 1,995 41 4,432 0 2- 30B /ME -01 5/1/2009 24 2,107 42 4,442 0 2- 30B /ME -01 4/30/2009 24 3,001 46 4,525 0 2- 30B /ME -01 4/29/2009 20 2,454 37 3,701 0 2- 30B /ME -01 4/28/2009 24 3,001 46 4,525 0 2- 30B /ME -01 4/27/2009 14 1,729 26 2,608 0 2- 30B /ME -01 4/26/2009 13 1,578 24 2,379 0 2- 30B /ME -01 4/25/2009 24 3,001 46 4,525 0 2- 30B /ME -01 4/24/2009 24 3,001 46 4,525 0 2- 30B /ME -01 4/23/2009 24 3,001 46 4,525 0 2- 30B /ME -01 4/22/2009 24 2,923 69 3,641 0 2- 30B /ME -01 4/21/2009 24 2,934 91 3,239 2,410 2- 30B /ME -01 4/20/2009 24 2,803 86 3,071 2,431 2- 30B /ME -01 4/19/2009 0 0 0 0 0 2-30B/ME-01 4/18/2009 0 0 0 0 0 2- 30B /ME -01 4/17/2009 0 0 0 0 0 2- 30B /ME -01 4/16/2009 0 0 0 0 0 2- 30B /ME -01 4/15/2009 0 0 0 0 0 2- 30B /ME -01 4/14/2009 0 0 0 0 0 2- 30B /ME -01 4/13/2009 0 0 0 0 0 2-30B/ME-01 4/12/2009 0 0 0 0 0 2- 30B /ME -01 4/11/2009 0 0 0 0 0 2- 30B /ME -01 4/10/2009 0 0 0 0 0 2- 30B /ME -01 4/9/2009 0 0 0 0 0 2- 30B /ME -01 4/8/2009 17 879 21 757 866 2-30B/ME-01 4/7/2009 24 1,107 24 898 1,414 2- 30B /ME -01 4/6/2009 22 874 17 655 0 6 Attachment 2 - Weest Data III Total Form Gas Gas Fluid Oil Water Gas Lift Lift Rate Rate Rate Rate Rate Press Well Bore Run Date Hrs (bpd) (bpd) (bpd) (mscfd) (mscfd) (psi) Choke 2- 30B /ME -01 11/30/2009 4 625 620 5 1,808 2,615 1,065 176 2-30B/ME-01 11/9/2009 4 645 612 34 2,772 0 2,130 176 2- 30B /ME -01 10/28/2009 4 746 736 10 2,649 223 2,160 176 2- 30B /ME -01 10/24/2009 4 758 751 7 2,384 2,620 1,069 176 2- 30B /ME -01 10/20/2009 4 637 634 3 2,252 3,217 1,287 55 2- 30B /ME -01 10/15/2009 4 788 764 24 2,746 188 2,159 176 2- 30B/ME -01 10/15/2009 4 754 731 23 2,648 189 2,154 55 2- 30B /ME -01 10/3/2009 4 836 829 8 2,689 0 2,121 55 2- 30B /ME -01 9/24/2009 4 857 840 16 2,671 186 2,147 55 2- 30B /ME -01 9/12/2009 4 944 930 14 3,001 0 0 55 2- 30B /ME -01 9/8/2009 4 988 971 17 2,383 3,117 0 55 2- 30B /ME -01 9/4/2009 4 706 704 2 2,827 0 0 53 2- 30B /ME -01 8/17/2009 4 1,477 1,469 8 2,396 0 0 35 2- 30B /ME -01 6/26/2009 4 1,078 1,034 44 2,428 0 0 55 2- 30B /ME -01 6/24/2009 4 894 878 16 2,341 0 0 55 2- 30B /ME -01 6/11/2009 4 1,237 1,202 35 2,223 0 0 55 2- 30B /ME -01 6/5/2009 4 982 949 33 2,019 0 0 55 2 -30B /M E -01 5/29/2009 4 1,045 1,020 25 1,881 0 0 55 2-30B/ME-01 5/18/2009 4 1,143 1,128 15 1,835 0 0 55 2- 30B /ME -01 5/10/2009 4 1,103 1,090 13 2,437 0 0 55 2- 30B /ME -01 5/8/2009 4 1,694 _ 1,623 71 4,310 0 0 105 2- 30B /ME -01 5/4/2009 4 2,215 2,149 66 4,535 0 0 104 2- 30B /ME -01 5/1/2009 4 2,036 1,995 41 4,432 0 0 104 2- 30B /ME -01 4/23/2009 4 3,046 3,001 46 4,525 0 0 104 2- 30B /ME -01 4/22/2009 4 2,992 2,923 69 3,642 0 0 104 2- 30B /ME -01 4/21/2009 4 3,024 2,934 91 3,239 2,500 0 104 2- 30B /ME -01 4/6/2009 11 996 976 20 731 1,400 0 130 • f t � ! k I ; F% i , ; r ' \ ¢ f )_ ' SEAN PARNELL, GOVERNOR C ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ; ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 September 9, 2009 Mr. David J. Szabo Head of Resource Management l® � Alaska Consolidated Team O( BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519 -6612 RE: Request for a waiver of the gas oil ratio limitations of 20 AAC 25.240(a) for well 2- 30B /ME -01 to allow for continued reservoir evaluation. Dear Mr. Szabo: By letter dated and received by the Alaska Oil and Gas Conservation Commission (Commission) on August 24, 2009, BP Exploration (Alaska) Inc. (BPXA) requested a waiver, in accordance with 20 AAC 25.240(b)(3) to allow for continued testing of the 2- 30B/ME-01 well to acquire reservoir performance data to help determine future reservoir development. BPXA's request is hereby by granted under the conditions below. The 2- 30B /ME -01 well, in the Duck Island Unit, was drilled and completed in early 2009. The well targeted reserves that were not a part of any of the existing oil pools in the unit and began producing on April 6 2009. Cumulative production from the well has been a little more than 109 thousand barrels. Despite the relatively modest production from this well it is already approaching double its initial gas oil ratio (GOR) limitation established by 20 AAC 25.240(a). BPXA is still evaluating future development options for the reserves targeted by this well and thus has requested a GOR waiver under 25.24(b)(3) for "acquisition of pool performance data is necessary to determine an optimum reservoir management program." According to its request letter, BPXA plans to collect reservoir pressure surveys during the testing period. On August 24, 2009, John Garing of BPXA informed David Roby of the Commission's staff that the January 2010 estimate for the next pressure survey indicated in BPXA's letter was based, at least partially, on anticipated reservoir voidage at that time. A GOR limitation waiver through April 30 2010, will allow BPXA to gather and analyze the additional data needed to make future reservoir development plans and will also allow sufficient time for the Commission to conduct a hearing and issue an order if an application in accordance with 25.240(c) is determined to be necessary for the continued development of the reserves encountered by this well. • Mr. David J. Szabo September 9, 2009 Page 2 of 2 Based on the above, BPXA's request for a waiver of the GOR limitations of 20 AAC 25.240(a) is hereby granted under the following conditions: 1) This waiver expires at the end of the day on March 31, 2010; 2) BPXA must discuss the results of the testing program and plans for future development of the reservoir with the Commission no later than February 28, 2010; and 3) BPXA must inform the Commission in a timely manner if any aspects of the proposed testing program change. DONE at Anchorage, Alaska and dated September 9, 2009. Daniel T. Seamount, Jr. tp .pi s ill . rman Chair Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • David J. Szabo -'��'' Head of Resource Management Alaska Consolidated Team (ACT) BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519 -6612 (907) 561-5111 August 24, 2009 Phone: (907) 564 -4788 Fax: (907) 564 -4440 Email SzaboDJ 0 bp.com Web: www.bp.com Mr. Daniel Seamount Alaska Oil and Gas Conservation Commission D 333 W. 7th Avenue, Suite 100 /AU G z1 2009 Anchorage, AK 99501 r , � ! � r x t �. ; r 6e 4.`_ �,tG •i).t:t. +.; i1 �: �.t. €. s!on RE: Request for a waiver of the gas oil ratio limitations for Well 2- 30B /ME -01 E `. for continued reservoir evaluation Dear Mr. Seamount: In accordance with 20 AAC 25.240.B.3, BP as Operator of the Duck Island Unit and sole Working Interest Owner of lease ADL 34633 (Tract 13), hereby requests a waiver of the gas oil ratio limitations for Well 2- 30B /ME -01 for a continued reservoir evaluation program through April 30, 2010 to acquire reservoir performance (gas, oil and water trends) and pressure data to help determine the potential for additional reservoir development. During this period: • Production of fluids from the 2- 30B /ME -01 well will be produced through the Endicott facility and commingled at the surface. Well 2- 30B /ME -01 will be tested a minimum of two times per month during periods when the well is on production. Allocated data will be reported monthly using form 10 -405 as required by 20 AAC 25.230. • Depending on the volume and performance of fluid offtake, 1 or more pressure surveys will be acquired. Current work indicates that it will likely be January 2010 for the next pressure survey, thus the request for a waiver to April 30, 2010 to allow time to integrate data and meet with the Commission. Prior to April 30, 2010, BP will meet with the commission to discuss the appropriate way forward for this well. Should you have any questions, please contact John Garing at (907) 564 -5167. Sincerely, mfr( David J. Szabo 1 bp „t,,ffr. David J. Szabo Head of Resource Management Alaska Consolidated Team (ACT) BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519 -6612 (907) 561 -5111 August 21, 2009 Fax: (907) 564 -4440 Email SzaboDJ @bp.com Web: www.bp.com s a ,l E 2009 Mr. David Roby r �s Er 6�nattk, Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Transmittal of 2- 30B /ME -01 Well Powerpoint slides Dear David, Attached is a copy of the powerpoint slides reviewed in our recent technical discussion of the 2- 30B /ME -01 well. We request that the material be held confidential pursuant to AS 38.05.035(a)(8)(C) and 11 AAC 82.810(a). If you have any questions, please contact John Garing at (907) 564 -5167. Sincerely, Dat David J. Szabo Enclosure cc: John Garing Sam French Frank Paskvan R.L. Skillern Emeka Emembolu Endicott Files • t , . 22 BPXA WELL DATA TRANSMITTAL N31 /IITTAL E closedi are the material _is ±eft below. If you have any questions, please contact Joe Lastufka at (907)564 -4091 Delivery Contents Bottom SW Name Date Contractor Run Top Depth Depth Description MEASURED DEPTH LOG - ARC GR & RESISTIVITY/ ECOSCOPE GR, RESISTIVITY & DENSITY /NEUTRON 2- 30B /ME -01 03 -07 -2009 SCH 1 -2 5616 14207 POROSITY TRUE VERTICAL DEPTH (SUBSEA) LOG - ARC GR & RESISTIVITY/ ECOSCOPE GR, RESISTIVITY & DENSITY/ 2- 30B /ME -01 03 -07 -2009 SCH 1 -2 5300 10160 NEUTRON POROSITY CD -ROM - LDWG EDIT OF MWD LOG DATA IN TIF FORMAT, WITH FINAL PDS 2- 30B /ME -01 03- 07- 2,009 SCH DISPLAYS 1( / Please Sig an nd turn one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center AOGCC Christine Mahnken DNR Corazon Manaois - ► b - - >) 3 Petrotechnical Data Center LR2 -1 900 E. Benson Blvd. PO Box 196612 Anchorage. AK 99519-6612 • bp 0 R. L. Skillern ; fir:. ^u ( i C J Senior Landman - `k �_`; BP Exploration (Alaska) Inc. APR 2(r 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 DIVi _ , ,l (907)561.5111 0l l_ 1 \ t�i D GAF; F> Phone: (907) 564 -5567 Fax: (907) 564 -4264 Email SkilleRLObp.com April 28, 2008 Web: www.bp.com Mr. Kevin Banks, Acting Director Division of Oil & Gas State of Alaska, Department of Natural Resources 550 W. 7 Avenue, Suite 800 Anchorage, AK 99501 Re: Data Submittal for Tract and Lease Operations on ADL 034633 Duck Island Unit for Well 2- 30B /ME -01 Dear Mr. Banks: BP Exploration (Alaska) Inc (BPXA), as Duck Island Unit Operator, has completed the authorized well 2- 30B /ME -01 to evaluate the lvishak and Sag River Formations in a fault block east of the Eider Field through a sidetrack of the existing 2 -30A well. The 2- 30B /ME -01 was completed as a vertical well in April 2009 and is currently testing the production potential of the Sag River Formation. BPXA has submitted in April, 2009 via transmittals #93061, 93053, 93059, 93033 & 93054 to Kristin Dirks all available data requested by the Department in your letter dated 6- Jan -09 with the exception of PVT and geochemical analyses. The most recent transmittal ( #93061) was couriered on 23- April -09. Fluid and geochemical samples are still being evaluated by the laboratories. Final reports will be transmitted after they become available. If you have any concerns or questions regarding these submittals or subsequent well operations, please contact John Garing at 564 -5167. Sincerely, R. L. Skillern cc: Jane Williamson — Alaska Oil and Gas Conservation Commission File II STATE OF ALASKA APR 2 3 2009 ✓" ey ALASKA OIL AND GAS CONSERVATION COMMISSION t+ WELL COMPLETION OR RECOMPLETION REPORT AND LO ak6 Oil & Gas Cons. Commission Anchorage 1 a. Well Status: ® 00 - ❑ Gas ❑ Plugged ❑ Abandoned ❑ Suspended 1 b. Well Class: 20AAC 25.105 20AAC 25.110 -® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other No. of Completions One ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband j 12. Permit to Drill Number BP Exploration (Alaska) Inc. '' 44//2009 ,�r5�'� 208 -187 ' 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519 -6612 2/26/2009 / 50- 029 - 22228 -02 -00 - 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: `' 3/7/2009' END 2 - 30B /ME - 01- 3327' FSL, 2245' FEL, SEC. 36, T12N, R16E, UM Top of Productive Horizon: 8. KB (ft above MSL): 48.5'- 15. Field / Pool(s): 4493' FSL, 1033' FEL, SEC. 26, T12N, R16E, UM Ground (ft MSL): 13.4' Endicott Field / Undefined Total Depth: 9. Plug Back Depth (MD +TVD) $`-!f t it t$ hA k, 4601' FSL, 1092' FEL, SEC. 26, T12N, R16E, UM 14104' 10120' � ,_ 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x- 258961 y- 5982465 Zone- ASP3 14207' - 10219' ADL 034633 - TPI: x- 255102 y- 5989040 Zone- ASP3 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x- 255046 y- 5989149 Zone- ASP3 None 18. Directional Survey El Yes ❑ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): (Submit electronic and printed information Der 20 AAC 25.050) 6' - 12' ft MSL 1465 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): is/kY60oYms - ridr i!O DIR / GR / RES / PWD, IFR / CASANDRA, DIR / GR / RES / PWD, NEU / DEN, IFR / CASANDRA, ttSgF 6 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE To 1 BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED 30" Structural Surface 131' Surface 131' 30" Driven 13 -3/8" 68# NT80 Surface 2709' Surface 2709' 17 -1/2" 2025 cu ft PF 'E. 179 cu ft PF 9-5/8" 47# NT8OS /NT95HS Surface _ 5818' ,Surface 5404' 12 -1/4" 2764 cu ft Class 'G' 7" 26# L -80 / 13Cr80 Surface 14193' Surface 10205' , 8-1/2" 1263 cu ft LiteCrete (3.34), 286 cu ft Class 'G' (1.17), & Tieback of: 88 cu ft Class 'G' (1.16) 23. Open to production or injection? ® Yes ❑ No 24. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD) (MD +TVD of Top & Bottom; Perforation Size and Number): 3 -3/8" Gun Diameter, 6 spf 4 -1/2 ", 12.6#, 13Cr80 13674' 13608' MD TVD MD TVD 13790' - 13810' 9819' - 9838' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13810' - 13830' 9838' - 9858' 13829' - 13854' 9857' - 9881' DEPTH INTERVAL (MD) 1 AMOUNT & KIND OF MATERIAL USED Freeze Protect w/ 115 Bbls of Diesel 13790' - 13854' Frac'd (Post Rig) Sag River Sand w/ 72,380 #'s of 20/40 Carbolite. Placed 72,380 #'s behind pipe - 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): April 6, 2009 Gas Lift Date of Test: Hours Tested: PRODUCTION FOR OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS-OIL RATIO: 4/6/2009 11 TEST PERIOD 4 447 335 9 130 749 Flow Tubing Casing Press: CALCULATED OIL-BBL: GAS -MCF: WATER-BBL: OIL GRAVITY -API (CORR): Press. 129 800 24 - HOUR RATE♦ 976 731 20 Not Available 27. CORE DATA Conventional Core(s) Acquired? ❑ Yes E� No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. s fdit?ii a t None le- -D�?r ahvi5 if !,_._o OCI / '..A i ,1--' 6 Form 10-407 Revised 02/2007 • CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Colville 11045' 7866' None Tuff 13225 9283' HRZ 13525' 9567' Base HRZ 13774' 9804' Sag River 13779' 9809' Shublik 13856' 9882' Ivishak 13926' 9949' Kavik 14156' 10170' Formation at Total Depth (Name): Kavik 14156' 10170' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and � co r to the best of my knowledge. Ct4 koZ,/0? Signed Terrie Hubble Q 69. ► • Title Drilling Technologist Date END 2- 30B /ME-01 208 -187 Prepared By Name/Number Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Dave Johnson, 564 -4171 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM la: Classification of Service Wells: Gas Injection, Water Injection, Water - Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak -Off Test Summary Legal Name: 2 -30 Common Name: 2- 30B /ME -01 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 2/25/2009 LOT 5,818.0 (ft) 5,404.0 (ft) 9.10 (ppg) 1,100 (psi) 3,655 (psi) 13.02 (ppg) • • Printed: 4/13/2009 2:53:31 PM • BP EXPLORATION Page 1 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/9/2009 00:00 - 07:00 7.00 MOB P PRE RD Mud manifold & Rock washer. Pull Conveyor in. -Clear Rig floor of all Tools not needed for upcoming Opps. 07:00 - 10:00 3.00 MOB N WAIT PRE Wait on Weather. 10:00 - 12:00 2.00 MOB P PRE RU to RD Top Drive, Wind walls & Derrick. 12:00 - 21:30 9.50 MOB P PRE LD: Top Drive. - Install Block carriage. Lower Bridle lines. - Secure lines in Derrick. Rd Braces. -Blow down Rig floor. PU "C" section. - Bridle up. 21:30 - 22:30 1.00 MOB P PRE PJSM on Skidding the Rig floor. -Skid Rig floor. 22:30 - 00:00 1.50 MOB P PRE PJSM on moving off Well F -96. -Move Rig off Well F -96 onto Pad area. 2/10/2009 00:00 - 07:00 7.00 MOB P PRE Move Matts. Remove Cellar doors & Heaters. -Break Stack out in Cellar. -Pull Rig ahead and re -plug in Shop. -Lower Wind walls. -Make preps to lower Derrick. -RU & attach Boosters. 07:00 - 11:00 4.00 MOB N WAIT PRE -Warm up derrick and wait for temperature to go over -35 F. - Continue to RD rig floor. 11:00 - 12:00 1.00 MOB P PRE -LD derrick. -Move rig and spot same at entrance of MP -F pad. 12:00 - 21:30 9.50 MOB N WAIT PRE Suspend rig move (and camp move) upon request from MPU not to block the roads due to transformer failure on MP -L pad. Wait until MPU solved situation. 21:30 - 00:00 2.50 MOB P PRE -Move rig f/ MP -F pad. - Prepare camp f/ move. 2/11/2009 00:00 - 05:00 5.00 MOB P PRE -Move rig to Y @ access to MP camp. -Move camp. 05:00 - 09:00 4.00 MOB N WAIT PRE - Suspend rig move upon request f/ MPU. -Wait until fuel trucks resupplied MP. 09:00 - 16:00 7.00 MOB P PRE Cont. moving rig to MP road and Spine Road intersection. NOTE: finished moving camp to ice pad by SDI @ Endicott. 16:00 - 20:00 4.00 MOB N WAIT PRE -Wait on Tourpusher to come back f/ Leadership Safety Meeting. -Wait on Security. 20:00 - 00:00 4.00 MOB P PRE Cont. moving rig down Spine Rd to W -pad. 2/12/2009 00:00 - 01:30 1.50 MOB P PRE Cont. moving rig down Spine Road. Observed flat tire on rig (rig on Spine Road between W -pad and S -pad). 01:30 - 16:00 14.50 MOB N RREP PRE Change flat tire on rig. 16:00 - 00:00 8.00 MOB P PRE Cont. moving rig on Spine Road to J -pad. 2/13/2009 00:00 - 13:00 13.00 MOB P PRE Cont. moving rig on Spine Road past Central Check Point. Observed tire on rig in bad condition. 13:00 - 00:00 11.00 MOB N RREP PRE Change tire on rig. 2/14/2009 00:00 - 04:30 4.50 MOB N RREP PRE Finish changing tire on rig. 04:30 - 06:30 2.00 MOB N WAIT PRE Wait on Security to resume rig move 06:30 - 09:30 3.00 MOB P PRE Cont. moving rig towards Sag River ice road. 09:30 - 10:30 1.00 MOB P PRE Stop rig short of Sag River ice road to take on fuel and water. 10:30 - 15:30 5.00 MOB P PRE Cont. moving rig to "Y" @ beginning of Endicott Road. 15:30 - 19:00 3.50 MOB N WAIT PRE Stop rig move at this point, per Security, until blasting takes place at Duck Island gravel mine. Printed: 4/13/2009 2:53:37 PM • • BP EXPLORATION Page 2 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/14/2009 19:00 - 00:00 5.00 MOB P PRE Cont. moving rig on Endicott Road. 2/15/2009 00:00 - 02:30 2.50 MOB P PRE Cont. moving rig on Endicott Road to ice road. 02:30 - 04:00 1.50 MOB P PRE Move rig down ice road towards Endicott SDI. 04:00 - 06:30 2.50 MOB P PRE -Move rig around SDI pad towards main causeway. -Move rig down causeway to main island. 06:30 - 10:00 3.50 RIGU P PRE - Position rig on pad for booster RD. - Remove back boosters. PU BOP stack and place on stand. 10:00 - 12:00 2.00 RIGU P PRE -Put mouse hole in cellar and hang off same. - Install heaters and doors in cellar. 12:00 - 13:30 1.50 RIGU P PRE Hold ATP meeting w/ Endicott personnel. Both rig crews attended. 13:30 - 14:30 1.00 RIGU P PRE Remove front boosters. 14:30 - 16:00 1.50 RIGU P PRE - Prepare to raise derrick: release any lines tied to rig, inspect derrick, get air to drawworks, get tools ready, install pins. -Raise and pin derrick. 16:00 - 18:00 2.00 RIGU P PRE Set and secure wind walls. 18:00 - 21:00 3.00 RIGU P PRE -Skid rig floor to moving position. - Remove boosters frame. -Jack up rig to move over well. NOTE: get Unit Work Permit w/ Control Room and review Drill Site Inspection w/ Pad Operator. 21:00 - 22:30 1.50 RIGU P PRE Position rig over well. Shim cellar and set up stairs. 22:30 - 23:30 1.00 RIGU P PRE Skid rig floor to drilling position. 23:30 - 00:00 0.50 RIGU P PRE RD front wind wall cable. 2/16/2009 00:00 - 03:00 3.00 RIGU P PRE -Hook up steam heater on rig floor above tugger. - Bridle down, lower C section, hang and tie back bridle lines. -Move conveyor back into position. -Build platform and ramp for rock washer. 03:00 - 06:00 3.00 RIGU P PRE - Remove carriage from blocks. -Hang rig tongs. -Put tool board in place. -Spot and berm rock washer. 06:00 - 09:00 3.00 RIGU P PRE - Install lights on rig floor. -Built platform and ramp for bottom of beaver slide. -PU top drive and install roller assembly. 09:00 - 11:30 2.50 RIGU P PRE -Hook up electric lines to top drive. -Clear carriage, rollers, bridle line sheave off rig floor. - Mobilize mud manifold to rig floor. -Take on 9.1 ppg brine in pits. 11:30 - 17:30 6.00 RIGU P PRE - Install IBOP assembly on top drive. -C /O saver sub f/ 4 -1/2 IF to 4 HT38. MU torque ring. - Install stand pipe and cement line. - Install torque tube and link tilt yoke on top drive. SIMOPS: Hard line crew install hard line and tiger tank. 17:30 - 19:30 2.00 WHSUR P DECOMP - Install secondary valve on IA -RU lines to tree to take returns out hard line to tiger tank. -Check hard line w/ air. OK 19:30 - 21:30 2.00 WHSUR P DECOMP - Mobilize lubricator and install same on tree. Test lubricator to 500 psi x 5 min on chart. -Pull BPV. Observe no pressure. -RD lubricator. Printed: 4/13/2009 2:53:37 PM • • BP EXPLORATION Page 3 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/16/2009 21:30 - 22:30 1.00 WHSUR P DECOMP -Blow steam through hard line. -Test hard line w/ water to 1500 psi. Test good. Blow down line. - Connect tubing to hard line and injection line to IA. 22:30 - 23:30 1.00 WHSUR P DECOMP Displace out freeze protect: -Pump 10 bbls 9.1 ppg brine down IA, taking returns out tubing to tiger tank. 84 gpm @ 240 psi. -Blow down lines. Swap lines to pump down tubing. -Pump 20 bbls 9.1 ppg brine down tubing, taking returns out IA to tiger tank. -Blow down lines. Allow diesel remains to migrate x 30 min. -Pump 10 bbls 9.1 ppg brine down tubing, taking returns out IA to tiger tank. -Blow down lines and RU returns to pits. 23:30 - 00:00 0.50 WHSUR P DECOMP Circulate well w/ 9.1 ppg brine. 126 gpm - 210 gpm 0 380 psi - 950 psi. 2/17/2009 00:00 - 01:00 1.00 WHSUR P DECOMP Cont. circulating well w/ 9.1 ppg brine w/ 1 drum "SafeScav" in system. Circulate all the way around w/ 229 bbls. 126 gpm - 210 gpm Cud 380 psi - 950 psi. 01:00 - 03:30 2.50 WHSUR P DECOMP - Verify well static. -Blow down lines. - Cameron Rep. dry rod TWC. RU to test same. -Test TWC f/ above to 4000 psi x 10 min on chart. -Test TWC f/ below to 1000 psi x 10 min on chart. 03:30 - 04:30 1.00 WHSUR P DECOMP ND dry hole tree. -Check top threads in tubing hanger. OK -Check 4 -1/2" TDS pin x 4 -1/2" IF box XO on top of tubing hanger. 9 -1/2 turns to MU Tested barriers are PPOT -T, MIT -IA, cement plug and tubing hanger w/ TWC. 04:30 - 09:00 4.50 BOPSUF P DECOMP -NU BOP - Install choke line, riser and flow line. 13 -5/8" 5M BOP stack configuration: - Annular preventer - 4 -1/2" x 7" VBR (top rams) - Blind Rams - Mud cross - 2 -7/8" x 5" VBR (bottom rams) 09:00 - 10:00 1.00 BOPSUF P DECOMP RU to test BOP 10:00 - 14:30 4.50 BOPSUF P DECOMP Testing BOP and related equipment per BP / AOGCC procedures and regulations. Testing to 250 psi low - 4000 psi high x 5 min each on chart w/ 4 -1/2" test jt. Test annular preventer to 250 psi low - 2500 psi high x 5 min each on chart w/ 4" test jt. Test witnessed by WSL, Toolpusher and Lou Grimaldi, AOGCC Rep. -When testing valves 9 and 11 in choke manifold observed part of the choke manifold frozen. 14:30 - 16:00 1.50 BOPSUF P DECOMP -Pump 110 F brine through choke manifold and steam same from the outside until thawing frozen section. - Perform koomey test while thawing choke manifold: 1. System Pressure: 2950 psi Printed: 4/13/2009 2:53:37 PM • BP EXPLORATION Page 4 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/17/2009 14:30 - 16:00 1.50 BOPSUF P DECOMP 2. Pressure after close: 1700 psi 3. 200 psi attained at 39 sec 4. Full pressure attained at 3 min 08 sec 5. Nitrogen bottles: 4 x 2200 psi avg. 16:00 - 21:30 5.50 BOPSUF P DECOMP Cont. testing BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 4000 psi high x 5 min each on chart w/ 4 -1/2" test jt. Test witnessed by WSL, Toolpusher and Lou Grimaldi, AOGCC Rep. - Tested 30 components: 1. 13 -5/8" annular 2. 4 -1/2" x 7" VBR (upper rams) 3. Blind rams 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. 4" Inside BOP, 4" FOSV (ball type), 5" Inside BOP, 5" FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP). -Did not test lower VBR at this point due to height of wellhead and spacing between top of tubing spool (with tubing hanger installed) and lower VBR. Lower VBR will be tested using test plug after pulling and LD 4 -1/2" tubing. -When changing test jt f/ 4 -1/2" to 7 ", observed that 4 -1/2" TDS x 4 -1/2" IF XO that goes below the test jt and screw into tubing hanger was damaged (hit nose on pin and gauled threads). Evaluate XO w/ Cameron Rep and considered that threads in tubing hanger may also be gauled. Decided to test top rams w/ 7" test jt later when testing lower VBR using test plug after pulling 4 -1/2" tubing. Also decided to use spear to pull tubing hanger to rig floor. 21:30 - 22:00 0.50 BOPSUF P DECOMP -RD testing equipment. -Blow down choke manifold, choke line and kill line. 22:00 - 00:00 2.00 WHSUR P DECOMP - Mobilize 6" OD lubricator extensions to rig floor, MU and install in BOP. Shut top rams. -MU lubricator. Test to 500 psi x 5 min on chart. -Pull TWC. RD lubricator and extensions. 2/18/2009 00:00 - 02:00 2.00 PULL P DECOMP - Finish LD lubricator extensions. - Mobilize bales, elevators and spear to rig floor. - Install bales and elevators. 02:00 - 03:30 1.50 PULL P DECOMP -MU spear to 1 jt 4" DP. -RIH and engage spear below tubing hanger. -Pull tubing hanger to rig floor. PUW 125k (block weight 50k). 03:30 - 04:30 1.00 PULL P DECOMP -Pump 40 bbls Safe Surf-O pill + 50 bbls 9.1 ppg brine + 40 Safe Surf-O pill. 252 gpm @ 1250 psi. - Circulate S/S w/ 9.1 ppg brine. 336 gpm @ 2020 psi. 04:30 - 07:30 3.00 PULL N WAIT DECOMP Endicott field goes to Phase III Weather Condition. Cont. circulating well w/ 9.1 ppg brine until weather conditions clear. 07:30 - 08:30 1.00 PULL P DECOMP -LD spear. -LD tubing hanger. Printed: 4/13/2009 2:53:37 PM • BP EXPLORATION Page 5 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/18/2009 08:30 - 09:30 1.00 PULL P DECOMP RU to pull and LD 4 -1/2" tubing: C/O elevators, RU power tongs. RU control line spooling unit. 09:30 - 11:30 2.00 PULL P DECOMP Pull and LD 4 -1/2" 12.6# L -80 IBM tubing to SSSV (35 jts). - Recover dual control lines and 37 SS bands. 11:30 - 12:00 0.50 PULL P DECOMP RD control line spooling unit. 12:00 - 18:00 6.00 PULL P DECOMP Cont. pulling and LD 4 -1/2" 12.6# L -80 IBM tubing and completion equipment. -Total tbg LD: 167 jts + 26.33' cutoff jt. -LD 2 GLMs assy. 18:00 - 19:30 1.50 PULL P DECOMP RD tubing handling tools and clean same. Clear rig floor. 19:30 - 20:30 1.00 BOPSUF P DECOMP - Mobilize test plug to rig floor and install same. RILDS to energize seal in test plug. -RU testing equipment. 20:30 - 23:00 2.50 BOPSUF P DECOMP -Test bottom rams to 250 psi low - 4000 psi high x 5 min each on chart w/ 4" and 5" test jt. -Test top rams to 250 psi low - 4000 psi high x 5 min each on chart w/ 7" test jt. -Tests witnessed by WSL, Tourpusher and Lou Grimaldi, AOGCC Rep. 23:00 - 00:00 1.00 BOPSUF P DECOMP -RD testing equipment. Pull test plug. -Blow down kill line. - Mobilize wear bushing to rig floor. 2/19/2009 00:00 - 00:30 0.50 WHSUR P DECOMP Install wear bushing. 00:30 - 01:00 0.50 CLEAN P DECOMP Inspect top drive. Lubricate rig. 01:00 - 01:30 0.50 CLEAN P DECOMP MU BHA w/ 6" bit + 7" casing scraper + bit sub + XO 01:30 - 08:00 6.50 CLEAN P DECOMP RIH w/ bit and casing scraper on 4" DP 1x1 f/ pipe shed to 6735'. 08:00 - 09:00 1.00 CLEAN P DECOMP Pump hi -vis sweep and circulate S /S. 521 gpm @ 2600 psi. 09:00 - 10:30 1.50 CLEAN P DECOMP -Slip and cut drilling line. - Service top drive. 10:30 - 13:30 3.00 CLEAN P DECOMP POOH 4" DP w/ 6" and 7" casing scraper to surface. 13:30 - 14:30 1.00 CLEAN P DECOMP -LD bit and casing scraper. - Mobilize scraper off rig floor. Clean rig floor. 14:30 - 15:30 1.00 EVAL P DECOMP -RU Schlumberger a -line equipment. - Mobilize USIT tool to rig floor. 15:30 - 16:00 0.50 EVAL P DECOMP RIH USIT tool on a -line to 2500'. No communication w/ tool. 16:00 - 23:30 7.50 EVAL N DFAL DECOMP -Pull USIT tool to surface and check head. -RIH USIT tool to 500', still no communication. -Pull back to surface, check cable and eliminate bad portion. Rethread head. -RIH USIT tool to 2500'. Tool working OK. 23:30 - 00:00 0.50 EVAL P DECOMP Cont RIH w/ USIT tool on a -line f/ 2500' to 6600'. 2/20/2009 00:00 - 02:00 2.00 EVAL P DECOMP Take USIT log in 7" casing f/ 6650' to surface. 02:00 - 02:30 0.50 EVAL P DECOMP RD USIT tools. 02:30 - 03:30 1.00 DHB P DECOMP -RU setting tool and CCL/GR on a -line. -MU 7" bridge plug 03:30 - 05:30 2.00 DHB P DECOMP -RIH 7" bridge plug on a -line to 6650' (CCL depth). Top of plug @ 10' f/ CCL. C.O.E @ 11' f/ CCL -Log up and correlate f/ 6650' to 6470' (1st pass). -Run down to 6650'. Log up and observe tool stuck @ 6605' (CCL depth). -Tool moves down free, but does not come up. Max tension applied: 3300 lbs. Printed: 4/13/2009 2:53:37 PM BP EXPLORATION Page 6 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/20/2009 03:30 - 05:30 2.00 DHB P DECOMP - Decide to go down and set at best spot possible. -Run down free and observe collar @ 6671'. Position CCL @ 6668'. -Set plug (Top of plug @ 6678', C.O.E @ 6679). E -line tension before setting: 1900 lbs. Tesnion after setting: 1350 lbs. -Slack e-line on plug and verify setting. 05:30 - 06:30 1.00 DHB P DECOMP POOH a -line w/ CCUGR and setting tool. 06:30 - 07:00 0.50 DHB P DECOMP RD Schlumberger a -line equipment. 07:00 - 07:30 0.50 DHB P DECOMP -RU testing equipment. -Test 7" casing and bridge plug to 3000 psi x 15 min on chart. 07:30 - 08:00 0.50 WHSUR P DECOMP Pull wear bushing. 08:00 - 10:30 2.50 WHSUR P DECOMP -ND BOP. - Remove tubing spool. Tested barriers: cement plug and bridge plug in 7" casing. Hanger w/ primary packoff in OA tested to 2000 psi and monitored for no flow. 10:30 - 11:30 1.00 WHSUR P DECOMP -Tack weld casing slips to 7" casing. Install slip handles. -NU drilling spool. 11:30 - 14:00 2.50 BOPSUF P DECOMP -NU BOP 14:00 - 16:30 2.50 BOPSUF P DECOMP Change out spacer spool on choke line for longer one. Install choke line. 16:30 - 17:30 1.00 BOPSUF P DECOMP -RU testing equipment. -Close blind rams. Test breaks in stack, drilling spool and choke line to 250 psi low - 4000 psi high x 5 min each on chart. -RD testing equipment. 17:30 - 18:00 0.50 PULL P DECOMP - Mobilize cutter and tools to rig floor. -MU BHA w/ 7" casing cutter. 18:00 - 21:00 3.00 PULL P DECOMP RIH w/ casing cutter to 5868'. 21:00 - 22:00 1.00 PULL P DECOMP - Obtain parameters: PUW 130k / SOW 120k / ROTW 125k. TQ 2k @ 40 RPM. 126 gpm @ 420 psi. - Locate collar @ 5888'. -Set cutter @ 5880'. Cut 7" casing @ 5880'. 168 gpm @ 750 psi. 40 RPM. Pressure dropped to 250 psi when cut effective. 22:00 - 23:00 1.00 PULL P DECOMP Close annular and attempt to establish circulation via 7" x 9 -5/8" annulus. Pressure up to 3000 psi with no returns. 23:00 - 00:00 1.00 PULL P DECOMP -Pull cutter to 5755'. - Locate collar @ 5766'. Set cutter @ 5746'. - Cutting casing @ 5746. 40 RPM. 168 gpm @ 810 psi. 2/21/2009 00:00 - 01:30 1.50 PULL P DECOMP Cont. cutting casing @ 5746'. Work cutting parameters 210 - 400 gpm @ 800 - 1500 psi. 40 -50 RPM. Observe no progress in the cutting. 01:30 - 03:30 2.00 PULL P DECOMP -POOH to change knives in casing cutter. -C /O knives in casing cutter. 03:30 - 04:00 0.50 PULL P DECOMP Lubricate rig. Inspect top drive. 04:00 - 07:00 3.00 PULL P DECOMP RIH w/ casing cutter to 5696' 07:00 - 07:30 0.50 PULL P DECOMP Screw in T.D. - Obtain parameters -PUW 128k - SOW 120k - ROW 125K w/ 2k tq - Pumping w/ 2.8 bpm, 390 psi - Locate last cut attempt w/ knives at 5746' - Stop pumps - Rotate w/ 40 rpm - Bring on pumps w/ 3.0 bpm 430 psi - Increase pump to 6.5 bpm, 700 psi Printed: 4/13/2009 2:53:37 PM • 110 BP EXPLORATION Page 7 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/21/2009 07:00 - 07:30 0.50 PULL P DECOMP - Pressure drop to 425 psi when cut out 07:30 - 09:00 1.50 PULL P DECOMP PJSM on circ. out freeze protect -Close annular, open 9 5/8" x 7" to slop tank -Bring on pumps w/ 4.5 bpm, 750 psi - Returns observed at slop tank -Pump 40 bbls H.V. sweep, 40 bbl "Safe Surf O ", 40 bbls H.V. sweep -Circ. pills around taking to slop tank until clean brine back j -Final pump rate 8.3 bpm, 1500 psi 09:00 - 11:30 2.50 PULL P DECOMP Observe well -POH. LD cutter - Knives show good wear pattern 11:30 - 12:30 1.00 PULL P DECOMP MU spear assembly w/ packoff 12:30 - 13:00 0.50 PULL P DECOMP Engage 7" casing at wellhead -BOLDS - Pull 260k to break hanger /slips free -Pull casing to rig floor w/ 200k up wt 13:00 - 13:30 0.50 PULL P DECOMP CBU w/ 8 bpm, 310 psi -RU casing equip. -PJSM on LD casing 13:30 - 14:00 0.50 PULL P DECOMP - Release spear. LD spear and jt 4" DP. -Blow down top drive. 14:00 - 19:30 5.50 PULL P DECOMP Pull and LD 7" casing. -Total casing LD: 140 jts + 29.02' top cut jt + 19.98' bottom cutoff jt. 19:30 - 20:00 0.50 PULL P DECOMP RD casing tools. 20:00 - 20:30 0.50 FISH P DECOMP Mobilize tools for next BHA to rig floor. 20:30 - 22:00 1.50 FISH P DECOMP MU BHA w/ Spear assy. dress f/ 7" 29# casing + Bumper Sub + Jars + 6 -3/4" DCs (9). 22:00 - 00:00 2.00 FISH P DECOMP RIH w/ fishing BHA on 4" DP to 5712'. 2/22/2009 00:00 - 01:00 1.00 FISH P DECOMP - Obtain parameters: PUW 142k / SOW 126k. 630 psi @ 294 gpm. -Run down to 5746' and circulate on top of fish. - Engage fish. Jar twice to 100k over PUW until fish free. PUW 150k after fish free. 01:00 - 05:30 4.50 FISH P DECOMP POOH and LD 4" DP to pipe shed. 05:30 - 06:30 1.00 FISH P DECOMP -Rack back drill collars. -LD jars and spear assy. to pipe shed. 06:30 - 07:30 1.00 FISH P DECOMP -RU casing equipment. -LD fish: 2 full 7" casing jts + 19.02 cutoff jt (top) + 32.85' cutoff jt (bottom). 07:30 - 08:00 0.50 FISH P DECOMP RD casing equipment and demobilize f/ rig floor. 08:00 - 08:30 0.50 FISH P DECOMP -PU spear assy. f/ pipe shed. Break same. - Demobilize tools f/ rig floor. 08:30 - 09:00 0.50 WHSUR P DECOMP Install wear bushing. 09:00 - 09:30 0.50 FISH P DECOMP RIH 12 stands 4" DP f/ derrick. 09:30 - 10:30 1.00 FISH P DECOMP LD remaining 4" DP to pipe shed. 10:30 - 13:30 3.00 CLEAN P DECOMP -C /O saver sub on top drive to 4 -1/2" IF. -C/0 dies on iron roughneck to 5 ". -C/0 air slips inserts to 5 ". SIMOPS: Test 9 -5/8" casing to 2000 psi x 10 min. Good test. 13:30 - 16:00 2.50 CLEAN P DECOMP - Mobilize tools f/ cleanout BHA to rig floor. -MU cleanout BHA w/ window mill + string mills + 9 -5/8" casing Printed: 4/13/2009 2:53:37 PM 1110 BP EXPLORATION Page 8 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/22/2009 13:30 - 16:00 2.50 CLEAN P DECOMP scraper + Bumper sub + 6 -3/4" DCs (9 jts) + 5" HWDP (6 jts). 16:00 - 21:00 5.00 CLEAN P DECOMP -RIH w/ cleanout BHA on 5" Dp 1x1 f/ pipe shed to 5880'. Tag 7" casing stub w/ 5k. - Obtain parameters: PUW 180k / SOW 155k / ROTW 170k. 5k TQ @ 60 RPM. 21:00 - 22:30 1.50 CLEAN P DECOMP Pump hi -vis sweep. Circulate S /S. 420 gpm @ 640 psi. -Rack back one stand. Blow down top drive. 22:30 - 23:30 1.00 CLEAN P DECOMP Cut and slip drilling line. 23:30 - 00:00 0.50 CLEAN P DECOMP POOH to 4650'. 2/23/2009 00:00 - 00:30 0.50 CLEAN P DECOMP Lubricate rig. Inspect top drive. 00:30 - 02:00 1.50 CLEAN P DECOMP POOH f/ 4650' to BHA. 02:00 - 03:00 1.00 CLEAN P DECOMP -Rack back DCs and HWDP. -LD mill assy. to pipe shed. 03:00 - 04:00 1.00 DHB P DECOMP PJSM -RU Schlumberger a -line equipment. - Prepare setting tool and bridge plug. 04:00 - 08:00 4.00 DHB P DECOMP RIH 9 -5/8" bridge plug w/ CCL/GR on e-line. -Tie in w/ GR - Locate 9 5/8" collar at 5838' -Set BP at 5841' (3' below collar) POH w/ W.L. 08:00 - 08:30 0.50 DHB P DECOMP RU to test -Test bridge plug / 9 5/8" casing to 2000 psi f/ 15 min on chart -Good test - RD 08:30 - 09:00 0.50 CLEAN P DECOMP PU bullnose -RIH w/ DC's 09:00 - 14:00 5.00 CLEAN P DECOMP RIH PU 5" DP from pipeshed to 5687' 14:00 - 15:00 1.00 DHB P DECOMP PU 9 5/8" storm packer -RIH & set packer 1 stand below rotary -Test storm packer to 1000 psi f/ 10 min on chart -Good test 15:00 - 16:30 1.50 WHSUR P DECOMP Pull wear ring -PU Packoff running tool -BOLDS - Engage P.O. through stack -PU w/ no overpull - Pull to rig floor - Packoff split - Primary seal and junk ring left in wellhead 16:30 - 18:30 2.00 BOPSUF P DECOMP PJSM on ND / NU BOP's -ND BOPE 9 5/8" tested barriers: Tested 9 -5/8" bridge plug @ 5841' and tested 9 -5/8" storm packer at 90' OA tested barriers: MIT to 600 psi and monitored OA for minimum 48 hrs. 18:30 - 20:00 1.50 WHSUR P DECOMP -ND casing spool. - Remove old casing spool and tubing spool f/ cellar 20:00 - 23:00 3.00 WHSUR P DECOMP -Move new casing spool and tubing spool to cellar. - Install new packoff. -NU casing spool. Install double valve in annular. -Test break and packoff to 3000 psi x 30 min per Cameron rep. 23:00 - 00:00 1.00 BOPSUF P DECOMP NU BOP 2/24/2009 00:00 - 01:00 1.00 BOPSUF P DECOMP Continue to NU BOP equipment. 01:00 - 02:30 1.50 BOPSUF P DECOMP Install test plug. RU testing equipment. Printed: 4/13/2009 2:53:37 PM 1 '4 BP EXPLORATION Page 9 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/24/2009 01:00 - 02:30 1.50 BOPSUF P DECOMP -Test breaks in BOP Drilling Spool and Choke line. -Test to 250 psi low - 4000 psi high x 5 min each on chart. -RD testing equipment. -Test witnessed by TP & WSL. 02:30 - 03:00 0.50 WHSUR P DECOMP -Pull Test plug. - Install Wear bushing. 03:00 - 03:30 0.50 DHB P DECOMP RIH w/ running tool to +/- 90' md. - Release & retrieve storm packer per HES Rep. -Break packer and LD same. 03:30 - 04:00 0.50 DHB P DECOMP RIH and tag bridge plug @ 5,839' and (drill pipe measurement). -Slack 35k on plug. Holds OK. PU 5' to 5,834' md. 04:00 - 05:00 1.00 CLEAN P DECOMP Displace well w/ 9.1 ppg LSND mud. -Pump rate 390 gpm @ 340 psi. 05:30 - 06:00 0.50 CLEAN P DECOMP Calibrate depth tracking on Draw works f/ SLB - MWD. 06:00 - 09:00 3.00 CLEAN P DECOMP Blow down top drive. POOH. -POH from 5,834' and to the BHA @ 274' w/ 5" DP. 09:00 - 09:30 0.50 CLEAN P DECOMP Stand back BHA in derrick. 09:30 - 10:00 0.50 STWHIP P DECOMP MOB new (Whip Stock) BHA to Rig floor. 10:00 - 12:00 2.00 STWHIP P DECOMP MU Whip Stock assembly. -9 5/8" Gen -1 Whip stock, with 8" Window mill. 12:00 - 13:30 1.50 STWHIP P DECOMP Continue to MU Whip Stock assembly to 570' md. -9 5/8" Gen -1 Whip stock, with 8" Window mill. - Shallow test MWD. 13:30 - 14:00 0.50 STWHIP P DECOMP RIH w/ 5" DP from 570' to 5,839' md. -PUW 185k, SOW 160k. ' and set down on EZSV Bridge plug 14:00 15:00 1.00 STWHIP P DECOMP At 5,839' g p g and Anchor set. -NOTE: Stand count was off by 1 Stand. -Set Anchor prematurely. -Took Tool face w/ MWD (136 degrees L). -136 L = 180 degrees off plan -PU, Shear bolt @ 245k = 60k over. -Shear Anchor @ 270k = 85k over. 15:00 - 20:30 5.50 STWHIP N HMAN DECOMP Mix & pump Dry job. -POH from 5,839' to 570' md. 20:30 - 21:30 1.00 STWHIP N HMAN DECOMP Stand back HWDP & D.C's. -LD Bumper sub & MWD. 21:30 - 00:00 2.50 STWHIP N HMAN DECOMP PJSM. -PU & MU 1 Jt of 5" DP. PU & MU 35' of 9 5/8" Csg. - Swallow 5" DP with 9 5/8" Csg. -Pull Slips. - Lower 9 5/8" Csg into the Stack to the Wear ring. -Close Hydril on 9 5/8" Csg. -Strip Window Mill & Whip Stock up into 9 5/8" Csg. -Pull Csg & Whip Stock Assembly to Rig Floor. 2/25/2009 00:00 - 01:00 1.00 STWHIP N HMAN DECOMP Close Blind Rams. -Set Whip Stock on Blind Rams. -Strip 9 5/8" Csg off Whip Stock. -LD 9 5/8" Csg. LD Whip Stock. 01:00 - 02:00 1.00 STWHIP N HMAN DECOMP Clear Rig floor. -MOB new Starter Mill to Rig floor. - Install Starter mill. Printed: 4/13/2009 2:53:37 PM BP EXPLORATION Page 10 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/25/2009 02:00 - 04:00 2.00 STWHIP N HMAN DECOMP MU "New" Whip Stock and MWD. - Orient Whip Stock & MWD. -RIH w/ the rest of the BHA to 571' md. -Test MWD 445 gpm / 410 psi. 04:00 - 07:00 3.00 STWHIP N HMAN DECOMP RIH w/ Whip Stock on 5" DP from 571' to 5,769' md. 07:00 - 08:00 1.00 STWHIP P DECOMP PU single of DP. -Screw in - Obtain parameters - PUW 170k - SOW 160k. -Pump rate 470 gpm / 850 psi - Orient Whip Stock face to 44 degrees Right. -RIH w/ single (38' above BP) & PU stand f/ derrick. -Check orientation - Tag Bridge Plug at 5,839' md. -Set down and shear bottom trip anchor w/ 18k down. -PU to 15k over up wt to ensure BTA set. -Set down and shear mills from slide w/ 45k down wt. -Final toolface = 29 degrees right of highside. 08:00 - 16:00 8.00 STWHIP P DECOMP Milling on window f/ 5,818' to 5,859' md. -TOW at 5 818' - ROW at 5 Rid' mrt p ' -Drill new hole to f/ mid window - 5826' to 5,859' md. 1 A -PUW 171k, SOW 160k, ROT wt 165k. -500 gpm / 1020 psi. -WOR 5 -15k RPM An Ca :1 - 7k Tq 16:00 - 16:30 0.50 DRILL P PROD1 Ream & back ream through window. -Work through window W/0 rotary per Baker rep. sir 16:30 - 18:30 2.00 DRILL P PROD1 Pump Hi Vis Sweeps surface to surface. -510 gpm / 1060 psi. - Reciprocate and rotate. -Metal shavings in sweep returns ( +/- 5 gallon bucket full). 18:30 - 19:00 0.50 DRILL P PROD1 Stand back 1 Std to 5,742' md. RU & perform LOT. -TOW is 5,818' and / 5,404' tvd. 1 - 5,404' tvd / 9.1 ppg / 1100 psi = 13 ppg EMW. -RD test equipment. 19:00 - 19:30 0.50 DRILL P PROD1 Monitor well - static. Pump dry job. -Blow down lines & Top Drive. 19:30 - 21:30 2.00 DRILL P PROD1 POH w/ 5" DP from 5,800' to 550' md, 21:30 - 23:30 2.00 DRILL P PROD1 Stand back 2 Stds HWDP. -LD D.C's., Bumper sub, MWD, XO's, 1 Jt HWDP. -LD Flex Jt, & Mills. -Upper Mill showed good wear pattern & was in gauge. 23:30 - 00:00 0.50 DRILL P PROD1 Pull Wear ring. 2/26/2009 00:00 - 00:30 0.50 DRILL P PROD1 Clear Rig floor of vendor Tools. 00:30 - 01:00 0.50 DRILL P PROD1 Flush Stack of metal cuttings with ported sub on 1 Jt of DP. 01:00 - 02:00 1.00 DRILL P PROD1 RU to test BOP's. 02:00 - 06:00 4.00 DRILL P PROD1 BOPE Test: -PJSM for testing BOPE's. -Begin testing BOPE's. - - -BOP Configuration: - Hydril GK 13 5/8" 5000. -4 1/2" X 7" Variables. -Blind Rams. - Drilling Spool. -2 7/8" X 5" Variables. Test BOP and related equipment. Printed: 4/13/2009 2:53:37 PM • BP EXPLORATION Page 11 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/26/2009 02:00 - 06:00 4.00 DRILL P PROD1 -Test per BP / AOGCC procedures and regulations. -Test to 250 psi low - 4,000 psi high x 5 min each on chart. -Test Hydril w/ 5" test jt to 250 / 2500 psi. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test choke valve #7. -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. -Test Top & bottom Rams w/ 5" test joint. -Test top Rams with 7" test Jt. -All tests are a Pass. Accumulator: -32 seconds for 200 psi increase. -2 minutes 42 seconds for full pressure. - Bottles 4 X 2150 psi. -Test witness waived by Bob Noble AOGCC. -Test witnessed by WSL & TP. 06:00 - 06:30 0.50 DRILL P PROD1 Install wear ring. 06:30 - 07:00 0.50 DRILL P PROD1 Mobilize BHA to rig floor. 07:00 - 10:30 3.50 DRILL P PROD1 MU: 8 1/2" Hycalog bit, 1.15 bent housing motor, MWD equip. -MU Flex DC's to 182' md. - Shallow test MWD w/ 570 gpm / 1050 psi. 10:30 - 11:30 1.00 DRILL P PROD1 PJSM. -PU 5" DP 1 X 1 from pipe shed to 1,000' md. 11:30 - 13:30 2.00 DRILL P PROD1 H2S alarm showing 13 ppm and climbing at shakers. - Driller shut in well w/ 20 ppm showing. *1 - Evacuated all personnel to Endicott Base Camp. - Security was alerted and rescue team was deployed to rig. - Toolpusher suited up and escorted rescue team into rig. -No H2S was detected on the rig. - Driller, WSL and electrician entered the rig. - Eletrician determined: -H2S detection head was faulty (Probably moisture). -Check for pressure on DP and annulus - OK. -Open well - Call all clear -AOGCC Rep. Bob Noble & John Crisp notified at 16:40 hrs 13:30 - 15:30 2.00 DRILL P PROD1 - Continue to PU 5" DP 1 X 1 from pipe shed to 3,110' md. 15:30 - 16:30 1.00 DRILL P PROD1 RIH w/ 5" DP from Derrick from 3,110' to 5,753' md. 16:30 - 17:30 1.00 DRILL P PROD1 Orient 29 degress "R" & Log from 5,753' to 5,835' md. -Ream under gauge hole from 5,835' to 5,859' md. -PUW 163k, SOW 155k. -462 gpm / 1120 psi. 17:30 - 22:30 5.00 DRILL P PROD1 Directionally drill ahead from 5,859' to 6,100' md. -PUW 165k, SOW 153k, ROT wt 157k. -WOB 12 -15k. RPM 60 / 2k Tq on / 5k Tq off. -553 gpm / 1660 psi on / 1450 psi off. 22:30 - 23:30 1.00 DRILL N SFAL PROD1 Stop drilling. Change out MWD monitor on drilling console. MWD screen failure 23:30 - 00:00 0.50 DRILL P PROD1 Directionally drill ahead from 6,100' to 6,164' md. -PUW 165k, SOW 153k, ROT wt 157k. -WOB 12 -15k. RPM 60 / 2k Tq on / 5k Tq off. -553 gpm / 1660 psi on / 1450 psi off. Printed: 4/13/2009 2:53:37 PM • BP EXPLORATION Page 12 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/26/2009 23:30 - 00:00 0.50 DRILL P PROD1 AST 2.13 hrs ART 0.8 hrs ADT 2.93 hrs. 2/27/2009 00:00 - 12:00 12.00 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 6,164' to 7,360' md. -PUW 175k, SOW 155k, ROT wt 166k. -550 gpm / 1600 psi off / 1820 psi on Btm. -WOB 10 -15k. RPM 80 / 2k Tq off / 5k Tq on Btm. AST 3.08 hrs ART 4.55 hrs ADT 7.63 hrs 12:00 - 00:00 12.00 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 7,360' to 8,608' md. -PUW 195k, SOW 165k, ROT wt 175k. -550 gpm / 1840 psi off / 2000 psi on Btm. -WOB 12 -15k. RPM 80 / 6k Tq off / 7 -9k Tq on Btm. - Pumped a Nut Plug Hi Vis Sweep @ 8,200' md. -Sweep results= 25% increase in cuttings. AST 2.38 hrs ART 4.36 hrs ADT 7.24 hrs. Total daily hrs: AST 5.46 hrs ART 8.91 hrs ADT 14.87 hrs 2/28/2009 00:00 - 12:00 12.00 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 8,608' to 9,631' md. -PUW 213k, SOW 169k, ROT wt 189k. -550 gpm / 1920 psi off / 2100 psi on Btm. -WOB 10k. RPM 80 / 8k Tq off / 9k Tq on Btm. -Pump Hi Vis Sweeps every 500'. AST 1.93 hrs ART 5.62 hrs ADT 7.55 hrs 12:00 - 00:00 12.00 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 9,631' to 10,672' md. -PUW 225k, SOW 170k, ROT wt 195k. -550 gpm / 2070 psi off / 2330 psi on Btm. -WOB 10 -15k. RPM 80 / 10k Tq off / 11k Tq on Btm. -Pump Hi Vis Sweeps every 500'. AST 2.46 hrs ART 5.46 hrs ADT 7.92 hrs. Total daily hrs: AST 4.39 hrs ART 11.08 hrs ADT 15.47 hrs 3/1/2009 00:00 - 10:30 10.50 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 10,672' to 11,533' md. -PUW 233k, SOW 182k, ROT wt 205k. -550 gpm / 2180 psi off / 2520 psi on Btm. -WOB 10 -15k. -RPM 80 -100 / 10k Tq off / 12k Tq on Btm. AST 0.92 hrs ART 3.83 hrs ADT 4.75 hrs -Pump Hi Vis Sweeps every 500'. 10:30 - 00:00 13.50 DRILL N WAIT PROD1 Field wide Phase III called at 10:30 hrs. -Stand back 1 stand. -CBU w/ 550 gpm / 2180 psi. - 20 rpm / 5k free Tq. -Slow pumps to 400 gpm / 1325 psi - 80 rpm. -Wait on weather. Printed: 4/13/2009 2:53:37 PM BP EXPLORATION Page 13 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/2/2009 00:00 - 08:30 8.50 DRILL N WAIT PROD1 Continue to wait on weather. - Rotate & reciprocate. - Circulate 400 gpm / 1300 psi. -RPM 30. 08:30 - 12:00 3.50 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 11,533' to 11,712' md. -PUW 233k, SOW 183k, ROT wt 207k. -550 gpm / 2090 psi off / 2260 psi on Btm. -WOB 10 -12k. -RPM 100 /9k Tq off / 11k Tq on Btm. AST 0.75 hrs ART 1 hrs ADT 1.75 hrs -Pump Hi Vis Sweeps every 500'. 12:00 - 21:00 9.00 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 11,712' to 12,088' md. -PUW 235k, SOW 185k, ROT wt 210k. -550 gpm / 2130 psi off / 2330 psi on Btm. -WOB 15k. -RPM 110 / 10k Tq off / 11k Tq on Btm. 21:00 - 22:30 1.50 DRILL N RREP PROD1 Work on pump. - Circulate Hi Vis Sweep S /S. - Reciprocate & rotate. - 420 gpm / 2210 psi. 115 RPM. 22:30 - 00:00 1.50 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 12,088' to 12,150' md. -PUW 235k, SOW 185k, ROT wt 210k. -550 gpm / 2110 psi off / 2310 psi on Btm. -WOB 15k. -RPM 110 /10kTg off /11kTgonBtm. -Pump Hi Vis Sweeps every 500'. AST 4.98 hrs ART 0.97 hrs ADT 5.95 hrs. Total daily hrs: AST 5.73 hrs ART 1.97hrs ADT 7.70 hrs 3/3/2009 00:00 - 11:00 11.00 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 12,150' to 12,559' md. -PUW 240k, SOW 185k, ROT wt 214k. -550 gpm / 2050 psi off / 2390 psi on Btm. -WOB 15k. -RPM 110 /10kTg off /11kTgonBtm. -Pump sweeps as needed. 11:00 - 12:30 1.50 DRILL P PROD1 Pump Hi Vis / Nut Plug sweep S.S. -R &R 100 rpm - 550 gpm / 2030 psi. - Obtain new SPR's. - Obtain parameters w/ no pump: -PUW 260k - SOW 200k. - Actual ECD= 10.33 ppg Calc ECD= 10.19 ppg AST 5.69 hrs ATR 0.86 hrs ADT 5.9 hrs 12:30 - 14:00 1.50 DRILL P PROD1 Blow down T.D. -POH on elevators to 11,052' md. -Ghost reamer was pulled up to 9,828' md. -No issues - max overpull = 15 -20k. Printed: 4/13/2009 2:53:37 PM • • BP EXPLORATION Page 14 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/3/2009 14:00 - 14:30 0.50 DRILL P PROD1 RIH to 12,465' md. -As precaution, wash last stand to bottom at 12,559' md. 14:30 - 17:30 3.00 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 12,559' to 12,612' md. -PUW 245k, SOW 190k, ROT wt 215k. -450 gpm / 1600 psi on Btm. -WOB 15k. 17:30 - 19:00 1.50 DRILL P PROD1 Pump 30 bbl Hi Vis Sweep. - Displace to 10.5 ppg GEM LSND mud. - Reciprocate & rotate. 100 RPM. -600 gpm / 2260 psi 19:00 - 20:00 1.00 DRILL P PROD1 Continue to circulate while cleaning and emptying Pits. - Circulate, reciprocate & rotate.40 RPM. -220 gpm / 630 psi. -Suck out & prepare pits 1 & 2. -Bring on more new mud. 20:00 - 00:00 4.00 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 12,612' to 12,696' md. -PUW 255k, SOW 185k, ROT wt 216k. -565 gpm / 2480 psi off / 2590 psi on Btm. -WOB 15k. -RPM 110 / 12k Tq off / 14k Tq on Btm. -Pump sweeps as needed. - Actual ECD= 11.48 ppg Calc ECD= 10.96 ppg AST 3.24 hrs ART 0.51 hrs ADT 4.4 hrs. Total daily hrs: AST 8.93 hrs ART 1.37 hrs ADT 10.3 hrs 3/4/2009 00:00 - 01:00 1.00 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 12,696' to 12,716' md. -PUW 255k, SOW 190k, ROT wt 215k. -550 gpm / 2520 psi off / 2800 psi on Btm. -WOB 15k. -RPM 100 /13kTg off /14kTgonBtm. -Pump sweeps as needed. 01:00 - 02:00 1.00 DRILL N RREP PROD1 Work on TOP Drive. - Rotation either 0 or maximum. - Repair Rotary Throttle Pot. 02:00 - 12:00 10.00 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 12,716' to 12,936' md. -PUW 255k, SOW 190k, ROT wt 215k. -550 gpm / 2520 psi off / 2800 psi on Btm. -WOB 15k. -RPM 100 / 13k Tq off / 14k Tq on Btm. -Pump sweeps as needed. - 12,936' and / 9,017' tvd. Actual ECD= 11.60 ppg Calculated ECD= 10.96 ppg AST 3.67 hrs ART 2.08 hrs ADT 5.75 hrs 12:00 - 00:00 12.00 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 12,936' to 13,173' md. Printed: 4/13/2009 2:53:37 PM • BP EXPLORATION Page 15 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/4/2009 12:00 - 00:00 12.00 DRILL P PROD1 -PUW 260k, SOW 190k, ROT wt 221k. -565 gpm / 2630 psi off / 2810 psi on Btm. -WOB 15k. -RPM 100 /12kTg off /14kTgonBtm. -Pump sweeps as needed. @ - 13,125' and / 9,185' tvd. Actual ECD= 11.40 ppg Calculated ECD= 10.86 ppg AST 4.85 hrs ART 0.71 hrs ADT 4.14 hrs. Total daily hrs: AST 8.52 hrs ART 1.37 hrs ADT 9.89 hrs 3/5/2009 00:00 - 07:30 7.50 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 13,173' to 13,595' md. -PUW 267k, SOW 198k, ROT wt 230k. -550 gpm / 2520 psi off / 2860 psi on Btm. -WOB 20 -25k. -RPM 100 / 13k Tq off / 15k Tq on Btm. -Pump sweeps as needed. TUFFS top called 13,227' and / 9,284' tvd. @ - 13,405' and / 9,457' tvd. Actual ECD= 11.51 ppg Calculated ECD= 11.33 ppg 07:30 - 08:00 0.50 DRILL P PROD1 Circulate sample to surface per Geologist 08:00 - 08:30 0.50 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 13,595' to 13,620' md. -PUW 267k, SOW 198k, ROT wt 230k. -550 gpm / 2600 psi off / 3040 psi on Btm. -WOB 20 -25k. -RPM 100 /13kTg off /15kTgonBtm. -Top HRZ called at 13,525' and / 9,568' tvd. 08:30 - 09:00 0.50 DRILL P PROD1 Circulate sample to surface per Geologist. 09:00 - 09:30 0.50 DRILL P PROD1 Continue directionally drilling ahead. -Drill ahead from 13,620' to 13,690' md. -PUW 267k, SOW 198k, ROT wt 230k. -550 gpm / 2600 psi off / 3040 psi on Btm. -WOB 20 -25k. -RPM 100 /13kTg off /15kTgonBtm. -@ 13,690' MD / 9723' TVD: Actual ECD= 11.75 ppg Calculated ECD= 11.32 ppg 09:30 - 10:30 1.00 DRILL P PROD1 Circulate H.V. sweep surface to surface. -MAD pass f/ 13,690' to 13,597' md. -550 gpm / 2450 psi - 100 rpm. 10:30 - 12:00 1.50 DRILL P PROD1 Stand back one stand of 5" DP -CBU. -MAD pass f/ 13,597' to 13,504' md. -550 gpm / 2450 psi - 100 rpm. AST 1.72 hrs ART 3.6 hrs ADT 5.32 hrs 12:00 - 13:00 1.00 DRILL N SFAL PROD1 RIH to TD at 13,690' md. Printed: 4/13/2009 2:53:37 PM • BP EXPLORATION Page 16 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/5/2009 12:00 - 13:00 1.00 DRILL N SFAL PROD1 -Rerun Mad pass per Schlumberger. -MAD pass from 13,690' to 13,567' md. -550 gpm / 2450 psi - 100 rpm. 13:00 - 15:00 2.00 DRILL P PROD1 Observe well - Static. Blow down T.D. - Initial PUW w/ no pumps = 295k. -POH on elevators wet to 11,617' md. -Strap out of the hole. -Pump dry job - Blow down. 15:00 - 20:30 5.50 DRILL P PROD1 POH w/ 5" DP from 11,617' to 5,664' and 20:30 - 22:30 2.00 DRILL P PROD1 Cut & Slip 1 1/4" Drilling line. - Double cut line = 119 ft. of cut line. - Service Top Drive. Adjust brake handle. 22:30 - 23:00 0.50 DRILL P PROD1 Lubricate Rig. 23:00 - 00:00 1.00 DRILL P PROD1 Pump Hi Vis Sweep surface to surface. - Reciprocate & rotate. 100 RPM -550 gpm / 2130 psi. 3/6/2009 00:00 - 00:30 0.50 DRILL P PROD1 Monitor well - Static. -Pump Dry job. Blow down Top drive. 00:30 - 01:00 0.50 DRILL P PROD1 LD Bad stand of 5" DP. - Washout in top Jt. 01:00 - 03:00 2.00 DRILL P PROD1 POH w/ 5" DP from 5,664' to 364' md. - Continue SLM. No correction. 03:00 - 03:30 0.50 DRILL P PROD1 Weekly BOP funtion test. - Function test: Hydril, Top & Bottom Rams, -HCR Kill & Choke. Test Accumulator 03:30 - 04:30 1.00 DRILL P PROD1 Rack back HWDP & Collars. -LD: XO & Stabilizer. 04:30 - 06:00 1.50 DRILL P PROD1 Down load MWD. -LD: MWD, In -line Stabilizer, ARC, Mud motor & Bit. - Handle BHA. 06:00 - 06: 0 06:30 0.50 DRILL P PROD1 Clear Rig floor of all Tools not needed for upcoming Ops. 06:30 - 07:00 0.50 DRILL P PROD1 Clean Rig floor. 07:00 - 10:30 3.50 DRILL P PROD1 PU: Ecoscope, NB Stab, Bit, Telescope MWD. -PU Stethescope LWD to 223' md. Verify communication. -PJSM and Load Nukes. 10:30 - 12:00 1.50 DRILL P PROD1 RIH w/ BHA on 5" DP from 223' to 2,777' md. -Pulse test @ 511' md. Fill pipe @ 2,777' md. 12:00 - 18:30 6.50 DRILL P PROD1 RIH from 2,777' to 5,803' md. Fill pipe @ 5,803' md. - Continue to RIH from 5,803' to 13,545' md. -No problems with BHA running through window. -Fill pipe every 20 Stds. 18:30 - 19:30 1.00 DRILL N SFAL PROD1 Make depth correlation corrections. - Repair signal harmonic problem. 19:30 - 21:00 1.50 DRILL P PROD1 Mad pass from 13,600' to 13,690' md. 21:00 - 00:00 3.00 DRILL P PROD1 Directionally drill ahead from 13,690' to 13,828' md. -PUW 285k, SOW 200k, ROT wt 240k. -550 gpm / 2550 psi on / 2420 off Btm. -WOB 15 -25k. RPM 150 / 15 -20k Tq on / 15k Tq off. @ - 13,733' and / 9,765' tvd. Actual ECD= 11.84 ppg Calculated ECD= 11.32 ppg ART 2.16 hrs ADT 2.16 hrs Printed: 4/13/2009 2:53:37 PM BP EXPLORATION Page 17 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/7/2009 00:00 - 09:30 9.50 DRILL P PROD1 Directionally drill ahead from 13,828' to 14,207' md. — -14,207' and / 10,218' tvd = (8 1/2" T.D.) -PUW 303k, SOW 206k, ROT wt 245k. -520 gpm / 2420 psi off / 2540 psi on Btm. -WOB 15 -25k. RPM 150 / 17k TQ on / 15k Tq off Btm. - Obtain formation pressure samples: -@ 13,870' and / 9,896' tvd = 9.15 ppg. -@ 13,914' and / 9,938' tvd = 9.25 ppg. @ 13,827' and / 9,854' tvd: - Actual ECD= 11.45 ppg. Calculated ECD= 11.34 09:30 - 12:00 2.50 DRILL P PROD1 Circulate up samples per geologist. -Pump H.V. Sweep around. -500 gpm / 2380 psi. -R &R w/ 130 rpm, 90' strokes. 12:00 - 00:00 12.00 DRILL P PROD1 Stethoscope readings. - Obtain formation pressure samples: - @ 14,132' and /10,147' tvd = 8.90 ppg. -@ 14,114' and /10,129' tvd = 8.90 ppg. -@ 14,102' and /10,118 ' tvd = 8.90 ppg. -@ 14,086' and /10,103' tvd = 8.90 ppg. -@ 14,052' and /10,070' tvd = 8.90 ppg. -@ 14,049' and /10,067' tvd = 8.90 ppg. -@ 14,046' and /10,065' tvd = 8.90 ppg. -@ 14,043' and /10,062' tvd = 8.90 ppg. -@ 14,040' and /10,059' tvd = 8.90 ppg. -@ 14,038' and /10,057' tvd = 8.90 ppg. -@ 14,034' and /10,053' tvd = 8.90 ppg. -@ 14,002' and /10,022' tvd = 8.90 ppg. -@ 13,984' and /10,005' tvd = 8.90 ppg. -@ 13,978' and / 9,999' tvd = 8.90 ppg. -@ 13,974' and / 9,995' tvd = 8.90 ppg. -@ 13,962' and / 9,984' tvd = 8.90 ppg. -@ 13,957' and / 9,979' tvd = 8.90 ppg. -@ 13,947' and / 9,970' tvd = 8.90 ppg. -@ 13,949' and / 9,972' tvd = 8.90 ppg. -@ 13,941' and / 9,963' tvd = 8.90 ppg. -@ 13,937' and / 9,960' tvd = 8.90 ppg. -CO 13,929' and / 9,952' tvd = 8.90 ppg. -@ 13,852' and / 9,879' tvd = 9.30 ppg. -@ 13,847' and / 9,874' tvd = 9.20 ppg. -@ 13,841' and / 9,868' tvd = 9.60 ppg. -@ 13,842' and / 9,869,' tvd = 9.20 ppg. -CO 13,823' and / 9,852' tvd = 9.10 ppg. PUW 275k, SOW 200k. -490 gpm / 2160 psi. 3/8/2009 00:00 - 02:00 2.00 DRILL P PROD1 Continue Stethoscope. Record formation pressures. -@ 13,820' and / 9,848' tvd = 9.10 ppg. @ 13,813' and / 9,841' tvd = 9.10 ppg. -@ 13,804' and / 9,833' tvd = 9.10 ppg. Printed: 4/13/2009 2:53:37 PM • BP EXPLORATION Page 18 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/8/2009 00:00 - 02:00 2.00 DRILL P PROD1 500 gpm / 2230 psi. -PUW 290k, SOW 210k. 02:00 - 03:00 1.00 DRILL P PROD1 Day light savings time. - Spring ahead. 03:00 - 03:30 0.50 DRILL P PROD1 Continue Stethoscope. Record formation pressures. -Cad 13,795' and / 9,824' tvd = 9.10 ppg. -@ 13,850' and / 9,877' tvd = 9.20 ppg. 500 gpm / 2230 psi. -PUW 290k, SOW 210k. 03:30 - 04:30 1.00 DRILL P PROD1 MRIL logging from 13,958' to 13,948' md. -Noted 50k over during first pass. Work pipe & circulate. -Re - MRIL logging from 13,958' to 13,948' md. -Noted 30k over pull. 04:30 - 05:00 0.50 DRILL P PROD1 Ream from 14,020' to 14,207' md. -Take check shot surveys @ 14,020' & 14,114' md. -520 gpm / 2320 psi. 100 rpm / 1k free Tq. 05:00 - 07:30 2.50 DRILL P PROD1 Circulate hole clean. -Pump Hi Vis Sweep surface to surface. - Reciprocate and rotate 90' strokes / 100 rpm. -500 gpm, 2230 psi. -No significant cuttings observed at shakers - Hole clean. 07:30 - 09:30 2.00 DRILL P PROD1 Blow down. -POH for short trip f/ 14,207' to 11,661' md. -Max overpull observed - 15 -20k. 09:30 - 10:30 1.00 DRILL P PROD1 Pump- H.V. Sweep. -600 gpm / 2700 psi. -R &R w/ 120 rpm, 12k torque. -Small amount of fine cuttings observed at shakers w/ sweep back. 10:30 - 12:00 1.50 DRILL P PROD1 Blow down. -RIH f/ 11,661' to 14,114' md. -As precaution, wash last stand to bottom. 12:00 - 16:00 4.00 DRILL P PROD1 Break circulation © 500 gpm / 2190 psi. -Pump Hi Vis Sweep surface to surface. - Reciprocate & rotate 90' stroke, 120 rpm. -Tq 16k. Pump 350 gpm / 1940 psi on down stroke. Rack back 1 Std, CBU, rack back 1 Std to 13,830' md. -Spot "G -Seal" pill. - Monitor well - Static. Pump Dry job. -Blow down Top drive. 16:00 - 20:30 4.50 DRILL P PROD1 POH w/ 5" DP from 13,830' to 5,708' md, inside window. -Tight spots noted © 11,160' & 10,843' md. -Work through each 1 time - OK. 20:30 - 21:30 1.00 DRILL P PROD1 Pump Hi Vis Sweep surface to surface. - Reciprocate pipe in 90' strokes. -600 gpm / 2240 psi. Hole clean. 21:30 - 00:00 2.50 DRILL P PROD1 Continue to POH w/ 5" DP from 5,708' to 2,200' md. 3/9/2009 00:00 - 02:00 2.00 DRILL P PROD1 Continue to POH w/ 5" DP to BHA © 233' md. -LD: HWDP, Jars & XO's. 02:00 - 04:30 2.50 DRILL P PROD1 LD DC's, Plug into MRIL. -PJSM on NUKES. Download MWD. Printed: 4/13/2009 2:53:37 PM • BP EXPLORATION Page 19 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/9/2009 02:00 - 04:30 2.50 DRILL P PROD1 -LD Stethescope, Telescope & ecoscope. -LD MWD, NB stab and Tools. 04:30 - 05:30 1.00 CASE P PROD1 Clear Rig floor of all Tools not required. -Clean Rig floor. Remove Elevators. - Remove Roughneck track. 05:30 - 08:00 2.50 CASE P RUNPRD MOB Csg equipment to Rig floor. -Steam equipment. Rig up. 08:00 - 12:00 4.00 CASE P RUNPRD PJSM. -Run 7" Liner per running order. -Run 7" Liner to 900' md. -Run 7 ", 26 #, 13Cr80, Hyd 521 Liner (1st 40 Jts). -Run 2 Straight Blade Cents w/ Stop ring in middle (Jts 1 -16). - Utilize "Jet Lube Seal gaurd" thread compound. - Optimum make up torque is 10,100 ft/lbs. -Fill Liner every 10 Jts. @ Window - PU 170k / SOW 160k. 12:00 - 00:00 12.00 CASE P RUNPRD Continue to run 7 ", 26 #, L -80, Hyd 521 Liner (Jts 41 -219). -Run 7" Liner from 900' to 8,522' md. -Run 1 free floating Centralizer on Jts 17 -219. - Utilize "Jet Lube Seal gaurd" thread compound. - Optimum make up torque is 10,100 ft/Ibs. @ Last Liner Jt # 219 - PU 205k / SOW 160k. 3/10/2009 00:00 - 02:30 2.50 CASE P RUNPRD Continue to run 7" Liner in hole: -PU Baker "Flex Lock" Liner hanger assembly. -Mix and add Baker "PAL polymer mix ". - Install in Tie Back sleeve and let set up. - Reciprocate pipe while waiting on PAL. -PU 1 Std of 5" DP to 8,620' and and circulate down. -Break circulation @ 210 gpm / 800 psi. - Rotated 10 rpm / 14k Tq. Neutral wt was 155k. -Work pipe 10 rpm = 8k Tq. -Work pipe 20 rpm = 8k. -Did not rotate 5 rpm due to potential backlash.. - Circulate 1 liner volume 210 gpm / 700 psi. - Initial with pumps on PU 189k, SOW 155k -Final pumps off PU 210k, SOW 165k. 02:30 - 06:30 4.00 CASE P RUNPRD RIH w/ 5" DP out of the Derrick (90 sec / Std) to 14,103' md. 06:30 - 10:00 3.50 CASE P RUNPRD Screw in T.D. - Obtain parameters - PUW 320k - SOW 180k -Break circ. w/ 3 bpm, 910 psi -Wash stand down to 14,193' -PU single - Attempt to break circ. - Packing off - PU 30' - Attempt to circ. w/ no success - Rotating w 10 -25 rpm, 15-21k torque - Establish circ. w/ 1.5 bpm 560 psi -Wash & ream to 14,193' - Taking weight -Stop rotary - Stage pumps up to 5 bpm 1040 psi Printed: 4/13/2009 2:53:37 PM • BP EXPLORATION Page 20 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B/ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/10/2009 06:30 - 10:00 3.50 CASE P RUNPRD - Circulate and condition mud dropping M.W. to 10.3 ppg -Work pipe 20' strokes -Wash down and taking weight at 14,193' 10:00 - 10:30 0.50 CASE P RUNPRD LD single -PU Baker TD head, cement lines 10:30 - 11:00 0.50 CASE P RUNPRD Break circ. w/ 3 bpm 910 psi -Stage pumps to 5 bpm, 1040 psi -Circ & condition mud -PJSM on Pumping Cement 11:00 - 12:30 1.50 CEMT P RUNPRD Give to Schlumberger -Pump 5 bbls mud push at 10.5 ppg -Test lines to 4500 psi -Pump 25 bbls mud push -Pump 225 bbls Lead cement - 11.0 ppg Lite Crete at 3.34 yield - 5.5 bpm 850 psi -Pump 51 bbls Tail cement - 15.8 ppg "G" at 1.17 yield - 5.2 bpm 300 psi -Drop dart - Kick out w/ 5 bbls H2O 12:30 - 14:00 1.50 CEMT P RUNPRD Give to rig - Displace w/ rig pumps using 10.3 ppg mud - 7 bpm - Caught cement at 55 bbls away -Did not observe dart latchup -Slow to 5.5 bpm, 270 psi -Slow to 3.5 bpm w/ 250 bbls away -Slow to 2 bpm at 380 bbls away -Bump plug w/ 4105 stks - 3000 psi - CIP at 14:10 hrs - Observe full circulation during all job. 14:00 - 14:30 0.50 CASE P RUNPRD -Set liner hanger w/ 3000 psi. Slack off to 95k to confirm hanger set. - Pressure up to 4200 psi to release hanger running tool. -PU 7' and expose dogs. Set down 40k while rotating 15 RPM and set liner top packer. -PU running tool above liner top packer. 14:30 - 16:00 1.50 CASE P RUNPRD -Pump hi -vis nut plug sweep and circulate S /S. 630 gpm @ 1500 psi. -Get 5 bbls of cement to surface on bottoms up. 16:00 - 17:00 1.00 CASE P RUNPRD -RD cement line. -LD 2 jts 5" DP and cement head. -Blow down cement line 17:00 - 19:00 2.00 CASE P RUNPRD -Cut and slip drilling line (59.5') - Inspect and service top drive, drawworks, blocks, crown and tugger sheaves. 19:00 - 23:00 4.00 CASE P RUNPRD -POOH and LD 5" DP to pipe shed. -LD liner running tool. - Mobilize polish mill assembly to rig floor. 23:00 - 00:00 1.00 CASE P TIEB1 RIH polish mill assembly on 5" DP from derrick. 3/11/2009 00:00 - 01:30 1.50 CASE P TIEB1 Cont. RIH w/ polish mill assy. on 5" DP f/ derrick to 5595'. 01:30 - 02:00 0.50 CASE P TIEB1 -MU top drive and obtain parameters: PUW 160k / SOW 145k / ROTW 153k. -Tag too of liner Cdt 5672'. Enter tieback Sleeve w/ polish mill assv. until taaging ton w/ top drPSsoff milt. - Polish tieback sleeve per Baker Rep. 02:00 - 03:00 1.00 CASE P TIEB1 Circulate well while spotting trucks and loading seawater in Printed: 4/13/2009 2:53:37 PM • • BP EXPLORATION Page 21 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/11/2009 02:00 - 03:00 1.00 CASE P TIEB1 pits. 03:00 - 05:30 2.50 CASE P TIEB1 Displace well from top of liner w/ 8.5 ppg seawater. 420 gpm @ 590 psi. -Clean under shale shakers. - Circulate to balance fluid. 05:30 - 08:30 3.00 CASE P TIEB1 POOH and LD 5" DP to pipe shed f/ 5672' to 2854'. 08:30 - 09:30 1.00 CASE P TIEB1 RIH remaining stands of 5" DP in derrick back to 5500'. 09:30 - 13:30 4.00 CASE P TIEB1 POOH and LD 5" DP to pipe shed f/ 5500' to surface. 13:30 - 14:00 0.50 CASE P TIEB1 - Service break polish mill assembly and LD same. -Purge kill line. 14:00 - 15:00 1.00 CASE P TIEB1 -RU testing equipment. -Test 9 -5/8" casing and 7" liner to 2000 psi x 30 min on chart. -RD testing equipment. 15:00 - 15:30 0.50 WHSUR P TIEB1 Pull wear bushing. 15:30 - 16:30 1.00 BOPSUF P TIEB1 Install test plug and RU to test BOP. 16:30 - 21:30 5.00 BOPSUF P TIEB1 Test BOP and related equipment per BP / AOGCC procedures and regulations. Test components to 250 psi low - 4000 psi high x 5 min each on chart w/ 4 -1/2" test jt. Test annular preventer to 250 psi low - 2500 psi high x 5 min each on chart w/ 4" test jt. Test upper rams w/ 4 -1/2" and 7" test jts. Test bottom rams w/ 4" and 4 -1/2" test jts. Test witnessed by WSL and Toolpusher/Tourpusher. Chuck Scheve, AOGCC Rep, waived witness of test. - Perform accumulator test: 1. System pressure: 2975 psi. 2. Pressure after close: 1700 psi 3. 200 psi attained I@ 36 sec. 4. Full pressure attained @ 2 min 47 sec. 5. Nitrogen: 4 bottles x 2175 psi avg. - Tested 29 components: 1. 13 -5/8" annular 2. 4 -1/2" x 7" VBR (upper rams) 3. Blind rams 4. 2 -7/8" x 5" VBR (lower rams) 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. 4" Inside BOP, 4" FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP). 21:30 - 22:00 0.50 BOPSUF P TIEB1 -RD testing equipment. Pull test plug. -Blow down choke and kill lines. 22:00 - 23:30 1.50 CASE P TIEB1 - Mobilize casing equipment to rig floor. -RU to run 7" tieback: 0/0 elevators, install casing tongs and torque turn equipment. 23:30 - 00:00 0.50 CASE P TIEB1 -PU tieback seal assy. w/ ported float collar. MU to 1st jt 7" 26# TCII. - Adjust casing tong installation. 3/12/2009 00:00 - 00:30 0.50 CASE P TIEB1 Finish adjusting casing tong and torque turn equipment. 00:30 - 09:00 8.50 CASE P TIEB1 Run 7" 26# L -80 TCII tieback w/ tieback seal assy. to 5594'. Total jts run to this point: 140. Printed: 4/13/2009 2:5337 PM • • BP EXPLORATION Page 22 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/12/2009 00:30 - 09:00 8.50 CASE P TIEB1 - Torque turn connections to 10100 Ibs -ft. - Bakerlok all connections in first 3 jts (below landing insert). 09:00 - 09:30 0.50 CASE P TIEB1 Mobilize casing pup jts and long bales to rig floor. 09:30 - 12:30 3.00 CASE P TIEB1 -MU 19.5' pup jt and jt #141. -MU 7" TCII pin x 4 -1/2" IF Box XO w/ head pin. RU to circulate. - Circulate 80 F seawater. 210 gpm @ 140 psi. - Obtain parameters: PUW 175k / SOW 170k. 12:30 - 13:30 1.00 CASE P TIEB1 -RD XO and head pin. -MU 14.72' pup jt on top of jt #141. -Run down and tag top of liner @ 5672'. Stab tieback seal assy. in tieback sleeve and slack off 20k on no -go. Mark pipe and PU 2'. -C /O bales (install long ones). -MU XO and cement head. RU cement line. -Slack off again on no -go (20k). Pressure test to 500 psi and verify seal. -PU 9' until ports in seal assy. exposed. 13:30 - 15:00 1.50 CEMT P TIEB1 -Break circulation. -Purge hard line to cementer w/ 86 F seawater. Pressure test line to 4000 psi. -Pump 60 bbls diesel w/ Little Red Services (freeze protect 7" x 9 -5/8" annulus). Drop bottom plug. - Schlumberger pump 15.6 bbls of 15.8 ppg class G cement. Kick out top plug w/ 5 bbls fresh water. 15:00 - 16:00 1.00 CEMT P TIEB1 -Turn to rig pumps. Displace w/ 86 F seawater @ 6 BPM / 230 psi. Slow pump rate to 2 BPM @ +/- 100 strokes prior to bump. -Bump plug w/ 2032 strokes. FCP =30 psi. Pressure up to 1530 psi. Bleed off pressure. -Slack off w/ 20k on no -go. Pressure up to 2500 psi x 10 min. Bleed off pressure and verify floats. PU to string weight. -CIP @ 16:00. 16:00 - 16:30 0.50 CEMT P TIEB1 RD cement head and XO 16:30 - 18:00 1.50 BOPSUF P TIEB1 -Blow down choke, kill and hole fill lines. Vac out stack. -Pull back flow line and drop riser. -RD choke line. -Break drilling spool. PU BOP & drilling spool to hang tieback on emergency slips. -Vac out tieback to cut. 18:00 - 19:30 1.50 WHSUR P TIEB1 - Prepare casing head f/ emergency slips. -Hang tieback on emergency slips w/ full string weight (125k). -Cut 7" jt. Break out XO on top of string. Pull and LD cutoff jt w/ pup jt. -Pull riser, remove drilling spool and set back BOP. 19:30 - 00:00 4.50 WHSUR P TIEB1 - Prepare 7" stub per Cameron rep. - Install tubing spool and packoff. Test packoff to 4300 psi x 30 min per Cameron rep. - Install secondary valve in IA. -NU BOP, C/0 spool on choke line. Install riser and flow line. SIM OPS: Mobilize cleanout BHA tools to rig floor. C/0 bales (install short bales). Printed: 4/13/2009 2:53:37 PM • . BP EXPLORATION Page 23 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/13/2009 00:00 - 04:30 4.50 BOPSUF P TIEB1 -Cont. 0/0 choke line spool. -0 /0 top rams to 3 -1/2" x 6" VBR. -0 /0 saver sub to 4" HT38. 0/0 pipe grabber and bell guide. - Install test plug and mouse hole. 04:30 - 07:00 2.50 BOPSUF P TIEB1 -RU testing equipment. -Test breaks in BOP, choke line and top rams to 250 psi low - 4000 nsi high x 5 min e.aeh an chart Tact tnp rams 0-1/2" Y F" VRB) w/ 4" and 4 -1/2" test jts. 07:00 - 07:30 0.50 BOPSUF P TIEB1 -RD testing equipment. -Pull test plug. 07:30 - 08:00 0.50 WHSUR P TIEB1 - Install wear bushing. -Blow down choke and kill lines. 08:00 - 09:00 1.00 CASE P TIEB1 MU cleanout BHA w/ 6 -1/8" bit + (2) boot baskets + 7" casing scraper + bit sub + jars + (6) 4 -3/4" DCs. 09:00 - 11:00 2.00 CASE P TIEB1 -RIH w/ cleanout BHA on 4" DP 1x1 to 2660' - Attempt to fill pipe. String plugged off. 11:00 - 12:30 1.50 CASE N DPRB TIEB1 -POOH and rack back 25 stands 4" DP (pulling wet). -Rack back 2 stands 4 -3/4" DCs. 12:30 - 14:30 2.00 CASE N DPRB TIEB1 -Break out bit sub and clean packed off scale. Re- install float valve. -Flush scale out of jars. -MU top drive to BHA and flush same. 14:30 - 19:30 5.00 CASE P TIEB1 RIH w/ cleanout BHA on 4" DP to 5550'. -Leave first 25 stands 4" DP racked back. -MU top drive and flush after PU 30 jts and 60 jts 4" DP. Then fill pipe every 75 jts (25 stands). 19:30 - 23:00 3.50 DRILL P TIEB1 -PU 1 stand 4" DP f/ derrick and MU top drive. -Wash down f/ 5550' to 5570'. Tag cement stringers. -Clean cement stringers f/ 5570' to 5578'. Tag plugs. -Drill out plugs and then landing insert @ 5582'. Cont. drill out cement to 5643'. -WOB 10 -15k / 60 RPM @ 2k torque / 165 gpm @ 260 psi. -PUW 130k / SOW 120k / ROTW 125k. 23:00 - 00:00 1.00 DRILL P TIEB1 Pump hi -vis sweep and circulate S/S until clean returns. 252 gpm @ 650 psi. - Reciprocate pipe while circulating to scrape cleaned area. 3/14/2009 00:00 - 00:30 0.50 DRILL P TIEB1 -Rack back 1 stand 4" DP. -PU 4 jts 4" DP 1x1 f/ pipe shed back to 5643'. 00:30 - 01:00 0.50 DRILL P TIEB1 Cont. drilling out cement f/ 5643' to 5681' (bottom of tieback seal assy.). -WOB 10 -15k / 60 RPM @ 2k torque / 245 gpm @ 490 psi. -PUW 130k / SOW 120k / ROTW 125k. 01:00 - 02:00 1.00 DRILL P TIEB1 Pump hi -vis sweep and circulate S/S until clean returns. 233 gpm @ 450 psi. - Reciprocate pipe while circulating to scrape cleaned area. 02:00 - 02:30 0.50 CASE P TIEB1 Lubricate rig. Inspect top drive. 02:30 - 10:00 7.50 CASE P TIEB1 Cont. RIH w/ cleanout BHA on 4" DP 1x1 to 11700'. 10:00 - 11:00 1.00 CASE P TIEB1 Cont. RIH w/ cleanout BHA on 4" DP stands f/ 11700' to 14104'. Tag landing liner collar. 11:00 - 12:00 1.00 CASE N DPRB TIEB1 Attempt to circulate and displace well w/ seawater: -Drill string plugged (pressure up to 3400 psi w/ no circulation). - Attempt to unplug string w/ no success. 12:00 - 19:30 7.50 CASE N DPRB TIEB1 POOH f/ 14104' to 230' (BHA). Pulling wet. Printed: 4/13/2009 2:53:37 PM ! • BP EXPLORATION Page 24 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/14/2009 19:30 - 20:00 0.50 CASE N DPRB TIEB1 -Rack back 2 stands 4 -3/4" DCs. -Break down jars, XO, bit sub, scraper, boot baskets and bit. -Clean boot baskets: cement cuttings /debris. 20:00 - 21:30 1.50 CASE N DPRB TIEB1 - Observe bit sub, XO and 4' inside jars plugged w/ scale. -Clean bit sub. Remove float valve f/ bit sub and clean. Install float valve back in bit sub. -Clean XO and jars. LD jars to pipe shed. -Run 2 stands 4 -3/4" DCs in hole. MU top drive and flush DCs. 21:30 - 22:00 0.50 CASE N DPRB TIEB1 -MU BHA w/ 6 -1/8" bit + bit sub w/ float valve + XO + 2 stands 4 -3/4" DCs. -RIH on 1 stand 4" DP. 22:00 - 23:30 1.50 CASE P TIEB1 -Cut and slip drilling line (59.5') - Inspect top drive, blocks, crown and drawworks. 23:30 - 00:00 0.50 CASE N DPRB TIEB1 RIH on 4" DP stands to 950'. 3/15/2009 00:00 - 06:30 6.50 CASE N DPRB TIEB1 Cont. RIH on 4" DP liner landing collar @ 14104'. -Fill and circulate pipe volume every 25 stands. 06:30 - 08:30 2.00 CASE P TIEB1 Displace well w/ clean seawater: -Pump 35 bbls hi -vis sweep + 50 bbls seawater + 80 bbls hi -vis sweep. Circulate S/S w/ clean seawater. -380 gpm @ 2900 psi. Rotate and reciprocate pipe, 80 RPM. 08:30 - 09:30 1.00 CASE P TIEB1 -RU testing equipment. -Test 7" liner and tieback to 4000 psi x 30 min on chart. Test good. -RD testing equipment. 09:30 - 18:30 9.00 CASE P TIEB1 POOH and LD 4" DP to pipe shed f/ 14104' to 190' (BHA). 18:30 - 19:00 0.50 CASE P TIEB1 LD BHA: (6) 4 -3/4" DCs, X0, bit sub, 6 -1/8" bit. 19:00 - 20:00 1.00 CASE P TIEB1 -Clean and clear rig floor. -Pull wear bushing. - Remove short bales and 4" elevators. 20:00 - 21:00 1.00 RUNCOMP RUNCMP -RU to run 4 -1/2" 13Cr80 Vam Top tubing: install long bales, 4 -1/2" elevators and compensator - install power tongs and torque turn equipment. -MU XOs to floor valves. 21:00 - 00:00 3.00 RUNCOMP RUNCMP -MU tail pipe assy: 4 -1/2" WLEG assy + 4 -1/2" XN nipple assy + 4 -1/2" X nipple assy w/ RHCM plug + 4 -1/2" x 7" S -3 production packer + 4 -1/2" X nipple assy. Bakerlok connections below packer. Torque turn connections to 4440 ft-Ibs. -RIH 4 -1/2" 12.6# 13Cr80 Vam Top tubing + completion equipment to 1200'. Torque turn all connections to 4440 ft -Ibs. 3/16/2009 00:00 - 00:30 0.50 RUNCOMP RUNCMP Lubricate rig. Inspect top drive. 00:30 - 12:00 11.50 RUNCOMP RUNCMP Cont. running 4 -1/2" 12.6# 13Cr80 Vam Top tubing and completion equipment f/ 1200' to 10131'. - Torque turn all connections to 4440 ft-Ibs. 12:00 - 12:30 0.50 RUNCOMP RUNCMP Inspect and service top drive, blocks and drawworks. 12:30 - 14:30 2.00 RUNCOMP RUNCMP Cont. running 4 -1/2" 12.6# 13Cr80 Vam Top tubing and completion equipment f/ 10131' to 12160'. Install SSSV - Torque turn all connections to 4440 ft -Ibs. 14:30 - 16:30 2.00 RUNCOMP RUNCMP - Mobilize and RU control line spooling unit. - Connect dual control lines to SSSV and pressure same to 5000 psi. 16:30 - 18:30 2.00 RUNCOMP RUNCMP Cont. running 4 -1/2" 12.6# 13Cr80 Vam Top tubing and Printed: 4/13/2009 2:53:37 PM • • BP EXPLORATION Page 25 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2-30B/ME-01 S p ud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/16/2009 16:30 - 18:30 2.00 RUNCOMP RUNCMP completion equipment f/ 12160' to 13644'. Installing dual control lines and SS bands. - Torque turn all connections to 4440 ft-Ibs. -Total jts tubing run: 319 -PUW: 210k / SOW: 130k (blocks weight: 50k) 18:30 - 20:30 2.00 RUNCOMP RUNCMP -MU tubing hanger and torque turn same to 4440 ft-lbs. -MU landing jt. - Install control lines in tubing hanger. -MU injection line on IA. -Clean tubing handling equipment. -Total SS bands installed on control line: 39 20:30 - 21:00 0.50 RUNCOMP RUNCMP -Land tubing hanger. RILDS. Bottom of WLEG © 13674'. -MU XO and head pin on landing jt. RU pressure hose to mud bucket line. 21:00 - 22:30 1.50 RUNCOMP RUNCMP Move fluids in pits and take on clean seawater f/ truck, to then move truck to suck from rockwasher (other truck on location broke and needed to call for replacement truck). 22:30 - 00:00 1.50 RUNCOMP RUNCMP Reverse circulate S/S w/ clean seawater. -Spot clean seawater w/ corrosion inhibitor between GLM w/ shear valve © 6717' and packer © 13608' 3/17/2009 00:00 - 00:30 0.50 RUNCOMP RUNCMP Finish reverse circulating w/ clean seawater. 00:30 - 03:00 2.50 RUNCOMP RUNCMP -Drop ball and rod. - Pressure up tubing to 4000 psi. Set packer. Hold 4000 psi in tubing x 30 min on chart. MIT -T good. -Bleed pressure in tubing to 2500 psi. - Pressure up IA to 4000 psi and hold x 30 min on chart. MIT -IA good. -Bleed off IA, then bleed off tubing. - Pressure up IA and observe DCK -2 valve shear © 2700 psi. -Pump down IA taking returns out tubing © 131 gpm / 2000 psi -Pump down tubing taking returns out IA © 144 gpm / 1700 psi 03:00 - 04:30 1.50 WHSUR P RUNCMP -RD XOs and head pin. -Break and LD landing joint. - Cameron Rep. dry rod TWC -Test TWC f/ below to 1000 psi x 10 min on chart. -Blow down lines and vac out stack. 04:30 - 06:00 1.50 BOPSUF P RUNCMP ND BOP. 06:00 - 10:00 4.00 WHSUR P RUNCMP -NU adapter flange and dry hole tree. -Test control lines to 5000 psi per Schlumberger Rep. Test adapter fainge to 5000 psi x 30 min per Cameron Rep. -Test dry hole tree w/ diesel to 5000 psi x 10 min on chart. 10:00 - 11:00 1.00 WHSUR P RUNCMP -RU lubricator. Test same to 500 psi x 5 min on chart. -Pull TWC. -RD lubricator 11:00 - 12:00 1.00 WHSUR P RUNCMP -RU lines to tree and IA. -Pump 100 bbls clean seawater w/ corrosion inhibitor down tubing, taking returns out IA. 126 gpm © 1620 psi. 12:00 - 17:00 5.00 WHSUR N WAIT RUNCMP Wait on weather: temperatures below -40F. Little Red Services unit not allowed to install lines and /or operate them under current temperatures. 17:00 - 20:30 3.50 WHSUR P RUNCMP -Spot Little Red Services trucks. RU lines. -Pump 115 bbls diesel down tubing, taking returns out IA, for freeze protect and to create pressure differential in tubing for Printed: 4/13/2009 2:53:37 PM • BP EXPLORATION Page 26 of 26 Operations Summary Report Legal Well Name: 2 -30 Common Well Name: 2- 30B /ME -01 Spud Date: 2/9/2009 Event Name: REENTER +COMPLETE Start: 2/9/2009 End: 3/17/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 3/17/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/17/2009 17:00 - 20:30 3.50 WHSUR P RUNCMP post rig perforating. -1.4 BPM @ 900 psi (FCP). -Wait 5 min and check static surface pressure on tubing: 500 psi. -RD Little Red Services. 20:30 - 21:30 1.00 WHSUR P RUNCMP -MU BPV on lubricator. - Install lubricator on tree. Open master and swab valves and check pressure on tubing before setting BPV: 560 psi. (pressure f/ U -tube effect f/ IA with 8.5 ppg seawater and tubing with diesel). - Install BPV. -Bleed remaining pressure in tree and RD lubricator. 21:30 - 22:00 0.50 WHSUR P RUNCMP Test BPV f/ below to 1000 psi x 10 min on chart. 22:00 - 00:00 2.00 WHSUR P RUNCMP -Blow down injection line. -RD lines to tree and IA. Remove secondary valve f/ IA. - Install gauges on OA, IA and tree. Secure tree and cellar. -OA = 0 psi / IA = 0 psi / Tree = 0 psi (after installing BPV). - Release rig @ 23:59 3 -17 -2009. Printed: 4/13/2009 2:53:37 PM END 2- 30B /ME -01, Well History (Post Rig Sidetrack) Date Summary 03/17/09 T /I /O = 0/0/0 Pulled 4" CIW TWC for Doyon 1. Used 1 -2" ext and tag @ 60" No problems. 03/18/09 T /I /O = 0/100/100 Replaced 2- 1/16" FMC O/A Valve. Pressure tested to 4600 PSI. Pulled 2- 1/16" FMC V/R Plug. Replaced 3 -1/8" McEvoy Valve, pressure tested valve to 4600 PSI, both valves did not leak. Pulled 3 -1/8" McEvoy V/R plug. NO PROBLEMS. 03/18/09 T /I /O = 560/560/0 Set 4 1/16 " CIW "H" BPV Thru Dry Hole Tree. Tag @ 92" (Doyon 14 move off.) 03/19/09 WELL S/I ON ARRIVAL. ASSIST BPV CREW PULL BPV. RIG UP SWCP # 4515. 03/20/09 T /I /0= 550/0/0 Pull 4" CIW H BPV thru dry hole tree. No ext used tagged @ 78. No problems. Post rig. 03/20/09 DRIFT W/ 3.84" NO -GO CENT TO DSSSV @ 1482' SLM W/ NO RESTRICTIONS. PULLED DSSSV FROM 1482' SLM. SET 4 -1/2" DSSSV PLUG BODY (4 x 3/16" eq- ports, oal= 42 ") IN SVLN @ 1482' SLM. SET P -PRONG (1.75" fn, od= 1.75 ", oal= 96 ") IN PLUG BODY @ 1482' SLM (top of prong @ 1478' slm). PERFORM SUCCESSFUL DRAW DOWN TEST ON DSSSV. LEFT WELL S /I, TURNED WELL OVER TO WELL TENDER. 03/21/09 T /I /O = 100/0/0 Set 4- 1/16" CIW "H" TWC thru Dry -hole tree for post rig tree replacement. 1- 2' ext. used, tagged @ 66 ". Complete. 03/21/09 T /I /O = 0/0/0 Removed dry hole tree, post Doyon 14. Replaced with 4 1/16 Cameron FLS with Baker actuator and Baker actuated wing valve. Torqued flange to specs. Did low pressure test to 500 psi for 5 min. Good test. Did high pressure test to 5000 psi for 15 min. Good test. Drained bore and secured well. 03/24/09 T /I /O /OO = 0/0/0/0 Pull 4" CIW H TWC # 256 thru tree. 1 -2' ext used tagged @ 98 ". Post tree swap and test. 03/29/09 WELL SHUT IN ON ARRIVAL. PULLED 4 -1/2" DSSSV PLUG FROM X NIP @ 1512' SLM. PULLED B &R FROM RHC @ 13631' MD. PULLED BK -DCK GLV FROM STA. #4 (6717' MD) & BK -DGLV FROM STA. #5 (3443' MD). SET BK -DOME GLV IN STA. #5 (3443' MD) & BK- OGLV IN STA. #4 (6717' MD). RIH W/ 4 -1/2" GS TO PULL RHC. 03/30/09 PULLED 4 -1/2" RHC FROM X NIP @ 13631' MD. DRIFT W/ 3 -3/8" DMY GUN, TEL, & SAMPLE BAILER. TT @ 13644' SLM = 30' CORR. TAGGED TD @ 14106', CORR MD 2' DEEPER THEN PBTD (14,104' MD). TURN WELL OVER TO WELL TENDER, LEFT WELL SHUT IN. 04/01/09 T /I /O /OO= 260 /ONAC /60. Temp = SI. T and IA FL (pre-perf). AL spool removed. T FL near surface. IA FL near surface. SV, WV = C. SSV, MV = 0. IA, OA, OOA = OTG. NOVP. /04/04/09 PERFORATED FROM 13829' - 13854' WITH GUN #1: 25' 3.38" HSD PJ 38406 GUNS, 6 SPF, 60 DEG PHASING. PERFORATION WAS DONE WITH WELL FLOWING (ASRC). MEMORY PRESSURE GAUGE DATA RECORDED. VISUAL AND SURFACE CONFIRMATION OF SHOTS FIRED. PERFORATED FROM 13810' - 13830' WITH GUN #2: 20' 3.38" HSD PJ 38406 GUNS, 6 SPF, 60 DEG PHASING. WELL SHOT SHUT IN. SURFACE AND VISUAL INDICATION OF SHOTS FIRED. 04/04/09 Well POP'd through separator while E -line in hole (underbalance perf). Drawdown well and S/I well for completion of perf job. Standby for E -line to complete job. Page 1 of 3 • END 2- 306 /ME -01, Well History (Post Rig Sidetrack) Date Summary 04/05/09 PERFORATED FROM 13790' - 13810' WITH GUN #3: 20' 3.38" HSD PJ 3406 GUNS, 6 SPF, 60 DEG PHASING. WELL SHOT SHUT IN. SURFACE AND VISUAL INDICATION OF SHOTS FIRED. FINAL T /I /O: 500/0/0 PSI. WELL TURNED OVER TO ASRC FOR WELL TEST. JOB COMPLETED. 04/05/09 E -line perf job complete. RDMO. Well POP thru separator. Stabilize well @ full open choke setting. Start 8 hour piggyback test. 04/06/09 Adperf flowback, abort test and 5/1 well due to electrical problems on unit. Well POP thru separator, open G/L to well and stabilize well. Start 24 hour piggyback test. 04/07/09 24 hour test cut short to 11 hour test. Stand by for approval to divert well out of separator. RDMO. 04/08/09 WELL FLOWING ON ARRIVAL. DRIFT W/ 2.50" CENT, 4 -1/2" TEL & 2.5" S- BAILER. LOC TT @ 13630' SLM + 44' = 13674' MD. TAGGED TD @ 14057' SLM + 44' = 14104' MD. (HARD BOTTOM, SAMPLE OF SAND) SET 4 -1/2" WHIDDON CATCHER SUB @ 13,617' SLM. CURRENTLY RIH TO PULL ST# 1 BK -DGLV. 04/09/09 PULL ST# 1 BK -DGLV (13,363' SLM), ST# 5 BK -LGLV (3,516' SLM), ST# 4 BK -OGLV (6,701' SLM). SET ST # 5 BK -DGLV (3,516' SLM), ST# 4 BK -DGLV (6,701' SLM). LRS ATTEMPT TO KILL WELL. UNABLE TO BRING DOWN PRESSURE. PULLED EMPTY 4 -1/2" WHIDDON CATCHER SUB (13,617' SLM). CURRENTLY RIH TO SET 4 -1/2" CAT STANDING VALVE. 04/09/09 T /I /O /0= 1300/1540/40/60 Load IA, Load TBG, Pumped 3 bbls neat meth, 50 bbls 1% KCL & 56 bbls 9.9 Brine. IA & TBG pressure up to 3100 psi. Call PE. Work plan change. 04/10/09 T /I /0= 1300/1540/40/60 Circ well, CMIT T x IA against standing valve & WV to 2500 PSI * ** *PASS * * * *, MIT IA to 3800 PSI ****PASS**** Pumped 19 bbls 1% KCL & 1 bbl neat meth down IA for CMIT. 1st 15 min loss of 0 PSI & 2nd 15 min loss of 0 PSI for a total loss of 0 PSI in 30 min. Pumped 199 bbls 1% KCL & 257 bbls 9.9 ppg brine to circ well. Capped w/ 15 bbls neat meth for freeze protect. Pumped 4 bbls neat meth down F/L for F /P. S/L sets Memory valve in bottom station. Pumped 9.2 bbls neat meth down IA to bring to test pressure. On 1st test, IA lost 0 psi in 1st 15 min & 0 psi in the 2nd 15 min. Pass. Bled IAP. S/L still on well. Well tender notifed upon departure. FWHP's = 1840/1500/40 IA, OA & OOA open to gauges. 04/10/09 SET 4 -1/2" CAT STANDING VALVE ON XN -NIP (13,626' SLM / 13,652' MD). PERFORM PASSING CMIT T x IA TO 2500 PSI AGAINST CAT STANDING VALVE. LRS LOAD TUBING AND IA 259 BBLS 9.9 BRINE & 225 BBLS KCL. SET PETRADAT SPMG (BK) IN STA. # 1 AT 13,363' SLM / 13,392' MD. LRS PERFORM PASSING MIT -IA WITH METH TO 3,800 PSI. ATTEMPT TO PULL 4 -1/2" CAT STANDING VALVE (13.626 SLM / 13,392' MD). 04/11/09 PULLED 4 -1/2" CAT STANDING VALVE FROM 13,626' SLM / 13,652' MD. SET 4 -1/2" FRAC SLEEVE AT 1,486' SLM / 1,512' MD. WELL LEFT S /I, TURN OVER TO WELL TENDER. 04/13/09 T /I /0= 280/1800/0/60 Assist Frac crew. Pumped a total of 14 bbls Diesel down IA to maintain pressure for frac crew. Bleed down IA to 500 Psi. RDMO / IA and OA open to gauges. Operator Notified. Frac crew on well @ time of departure. 04/13/09 RU Pump step rate, pump -in test followed by 150 bbl YF130LG Data frac ISIP of 2670 psi. Get design from town, 150 bbls pad 140bbIs 1# , 25 bbls each of 2# - 7# , 188 bbls 8# flushed with 170 bbls 10# and 36 bbls diesel. Final ISIP of 3060 psi 15 min 1260 psi. Total prop pumped 72,380 #'s. Close in well begin rigdown. Contact DSO close out permit. Job Complete. 04/14/09 WELL S/I ON ARRIVAL. RIGGING UP SLICKLINE UNIT IN PROGRESS. Page 2 of 3 • • END 2- 30B/ME -01, Well History (Post Rig Sidetrack) Date Summary 04/15/09 PULLED 4 -1/2" FRAC SLEEVE @ 1,486' SLM / 1,512' MD. TAGGED HARD TD @ 13,898' SLM W/ 3.0" CENT & S- BAILER. FRAC SAND RECOVERED IN BAILER. SET 4 -1/2" WHIDDON C -SUB @ 13,633' SLM / 13,652' MD. PULLED STA# 1 SPMG @ 13,361' SLM, STA# 5 DGLV @ 3,516' SLM & STA# 4 DGLV @ 6,701' SLM. 04/16/09 SET STA# 5 LGLV @ 3,516' SLM & STA# 4 S/O GLV @ 6,701' SLM. SET DGLV IN STA# 1 @ 13,363' SLM. PULLED EMPTY 4 -1/2" WHIDDON C -SUB @ 13,633' SLM. SET 4 -1/2" DMY SSSV (2.625" I.D.) @ 1,486' SLM / 1,512' MD. TESTED BOTH CONT /BAL -LINES TO 5000 PSI, BLED BACK TO 500 PSI. CURRENTLY RIH W/ 4 -1/2" CHECK SET, IN PROGRESS. 04/17/09 RUN 4 -1/2" CHECK SET TO DSSSV @ 1,486' SLM/ 1,512' MD. CAME BACK SHEARED. WELL LEFT S /I, JOB COMPLETE. I I Page 3 of 3 • ■ bp ,:,, , 4 Schlumberger : , 2- 30B/ME -01 Survey Report Report Date: 9- Mar -09 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 332.000° Field: Endicott Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: MPI / 2-30 TVD Reference Datum: KB Well: 2-30/0-09 TVD Reference Elevation: 48.5o ft relative to MSL Borehole: 2.30B /ME -01 Sea Bed / Ground Level Elevation: 13.40 ft relative to MSL UWI /API #: 500292222802 Magnetic Declination: 23.173° Survey Name / Date: 2-30B/ME-01 / March 9, 2009 Total Field Strength: 57731.493 nT Tort / AHD / DDI / ERD ratio: 188.008° / 7801.45 ft / 6.309 / 0.763 Magnetic Dip: 81.032° Grid Coordinate System: NAD27 Alaska State Planes, Zone 03, US Feet Declination Date: March 05, 2009 Location Lat/Long: N 70.35272935, W 147.95754124 Magnetic Declination Model: BGGM 2008 • Location Grid N/E Y/X: N 5982465.200 ftUS, E 258951.450 ftUS North Reference: True North Grid Convergence Angle: - 1.84365519° Total Corr Mag North -> True North: +23.173° Grid Scale Factor: 0.99996601 Local Coordinates Referenced To: Well Head Measured Azimuth Vertical Along Hole NS EW Comments Depth Inclination True Sub -Sea TVD TVD Section Departure Closure True North True North DLS Northing Easting Latitude Longitude (ft) (deg) (deg) (ft) (ft) (ft ) (ft) (ft) (ft ) (ft) (deg/100ft) (ftUS) (ftUS) RTE 0.00 0.00 0.00 -48.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5982465.20 258951.45 N 70.35272935 W 147.95754124 WRP 35.10 0.00 0.00 -13.40 35.10 0.00 0.00 0.00 0.00 0.00 0.00 5982465.20 258951.45 N 70.35272935 W 147.95754124 GYD CT DMS 93.17 0.33 29.37 44.67 93.17 0.09 0.17 0.17 0.15 0.08 0.57 5982465.34 258951.54 N 70.35272975 W 147.95754057 193.17 0.02 182.17 144.67 193.17 0.23 0.44 0.44 0.38 0.22 0.35 5982465.57 258951.68 N 70.35273038 W 147.95753943 293.17 0.06 147.59 244.67 293.17 0.16 0.51 0.40 0.32 0.25 0.04 5982465.51 258951.71 N 70.35273021 W 147.95753921 393.17 0.08 117.96 344.67 393.17 0.05 0.63 0.42 0.24 0.34 0.04 5982465.43 258951.80 N 70.35273000 W 147.95753848 493.17 0.12 38.51 444.67 493.17 0.04 0.78 0.55 0.29 0.47 0.13 5982465.47 258951.93 N 70.35273014 W 147.95753745 593.17 0.45 314.72 544.67 593.17 0.45 1.22 0.70 0.65 0.25 0.45 5982465.84 258951.72 N 70.35273112 W 147.95753919 693.17 0.95 332.10 644.66 693.16 1.66 2.43 1.71 1.66 -0.41 0.54 5982466.87 258951.09 N 70.35273387 W 147.95754460 793.17 1.92 326.02 744.63 793.13 4.15 4.93 4.16 3.78 -1.74 0.98 5982469.03 258949.83 N 70.35273967 W 147.95755535 893.17 3.27 338.95 844.52 893.02 8.65 9.44 8.66 7.83 -3.70 1.46 5982473.14 258948.00 N 70.35275074 W 147.957571 993.17 3.69 334.08 944.34 992.84 14.70 15.51 14.72 13.39 -6.13 0.51 5982478.78 258945.75 N 70.35276592 W 147.95759 1093.17 3.04 326.97 1044.17 1092.67 20.55 21.37 20.57 18.50 -8.98 0.77 5982483.98 258943.07 N 70.35277990 W 147.957614 1193.17 2.28 313.96 1144.06 1192.56 25.09 25.99 25.09 22.11 -11.86 0.97 5982487.68 258940.31 N 70.35278974 W 147.95763752 1293.17 1.74 316.06 1244.00 1292.50 28.44 29.50 28.46 24.58 -14.34 0.54 5982490.23 258937.90 N 70.35279650 W 147.95765770 1393.17 1.36 316.36 1343.96 1392.46 31.04 32.20 31.10 26.53 -16.22 0.38 5982492.24 258936.10 N 70.35280183 W 147.95767291 1493.17 1.21 318.15 1443.94 1492.44 33.21 34.45 33.30 28.18 -17.74 0.16 5982493.93 258934.63 N 70.35280633 W 147.95768527 1593.17 0.94 328.25 1543.92 1592.42 35.05 36.32 35.16 29.66 -18.88 0.33 5982495.45 258933.54 N 70.35281038 W 147.95769450 1693.17 0.73 319.38 1643.91 1692.41 36.49 37.77 36.61 30.84 -19.72 0.25 5982496.66 258932.73 N 70.35281361 W 147.95770137 1793.17 0.80 324.72 1743.90 1792.40 37.81 39.11 37.94 31.90 -20.54 0.10 5982497.74 258931.95 N 70.35281649 W 147.95770801 1893.17 0.64 312.25 1843.89 1892.39 39.03 40.36 39.18 32.84 -21.36 0.22 5982498.71 258931.16 N 70.35281907 W 147.95771464 1993.17 0.52 301.92 1943.89 1992.39 39.94 41.37 40.13 33.46 -22.16 0.16 5982499.35 258930.38 N 70.35282075 W 147.95772112 2093.17 0.31 300.76 2043.88 2092.38 40.57 42.09 40.79 33.84 -22.77 0.21 5982499.75 258929.78 N 70.35282178 W 147.95772614 SurveyEditor Ver SP 2.1 Bld( users) 2 -30\2- 30/0 - 09\2- 30B /ME- 01\2- 30B /ME -01 Generated 4/21/2009 2:16 PM Page 1 of 5 • Measured Azimuth Vertical Along Hole NS EW ' Comments Depth Inclination True Sub -Sea TVD TVD Section Departure Closure True North True North DLS Northing Easting Latitude Longitude _ (ft ) (deg) (deg) (ft) (ft ) (tt ) (ft) (ft) (ft) (ft ) (deg/100ft) (ftUS) (ftUS) 2193.17 0.36 273.90 2143.88 2192.38 40.96 42.67 41.23 34.00 -23.32 0.16 5982499.93 258929.24 N 70.35282222 W 147.95773057 2293.17 0.16 165.26 2243.88 2292.38 40.99 43.02 41.29 33.88 -23.60 0.44 5982499.82 258928.96 N 70.35282191 W 147.95773283 2393.17 0.32 144.74 2343.88 2392.38 40.58 43.43 40.88 33.52 -23.40 0.18 5982499.45 258929.14 N 70.35282092 W 147.95773123 2493.17 0.42 165.08 2443.88 2492.38 39.95 44.07 40.26 32.94 -23.15 0.16 5982498.86 258929.38 N 70.35281933 W 147.95772915 2593.17 0.35 197.45 2543.87 2592.37 39.38 44.72 39.73 32.29 -23.14 0.22 5982498.22 258929.36 N 70.35281756 W 147.95772913 2693.17 0.25 221.05 2643.87 2692.37 39.08 45.24 39.50 31.84 -23.38 0.16 5982497.77 258929.11 N 70.35281632 W 147.95773104 2793.17 0.15 244.73 2743.87 2792.37 39.01 45.59 39.48 31.62 -23.64 0.13 5982497.56 258928.84 N 70.35281572 W 147.95773316 2893.17 1.30 340.26 2843.86 2892.36 40.14 46.74 40.59 32.63 -24.14 1.32 5982498.59 258928.37 N 70.35281848 W 147.95773724 2993.17 3.50 342.73 2943.77 2992.27 44.26 50.93 44.58 36.61 -25.43 2.20 5982502.61 258927.21 N 70.35282936 W 147.95774770 3093.17 4.94 344.48 3043.50 3092.00 51.47 58.28 51.60 43.67 -27.49 1.45 5982509.73 258925.38 N 70.35284866 W 147.95776442 3193.17 6.40 343.10 3143.00 3191.50 61.14 68.16 61.17 53.16 -30.26 1.47 5982519.30 258922.92 N 70.35287456 W 147.95778693 3293.17 7.66 340.94 3242.25 3290.75 73.19 80.40 73.19 64.79 -34.06 1.29 5982531.05 258919.50 N 70.35290634 W 147.957817. 3393.17 9.10 333.68 3341.18 3389.68 87.68 94.96 87.70 78.18 -39.74 1.78 5982544.61 258914.25 N 70.35294292 W 147.95786389 3493.17 10.52 327.24 3439.72 3488.22 104.69 111.98 104.69 92.94 -48.19 1.79 5982559.64 258906.28 N 70.35298326 W 147.95793247 3593.17 11.83 319.16 3537.83 3586.33 123.78 131.33 123.80 108.38 -59.83 2.04 5982575.44 258895.14 N 70.35302542 W 147.95802702 3693.17 13.35 319.14 3635.42 3683.92 145.03 153.12 145.19 124.86 -74.09 1.52 5982592.38 258881.42 N 70.35307046 W 147.95814277 3743.17 14.38 319.44 3683.97 3732.47 156.72 165.10 157.00 133.95 -81.90 2.07 5982601.71 258873.90 N 70.35309528 W 147.95820621 3793.17 15.26 320.30 3732.30 3780.80 169.22 177.89 169.66 143.73 -90.14 1.81 5982611.75 258865.98 N 70.35312199 W 147.95827312 3843.17 15.91 319.81 3780.46 3828.96 182.37 191.33 182.97 154.02 -98.77 1.33 5982622.32 258857.69 N 70.35315013 W 147.95834315 3893.17 16.55 319.19 3828.47 3876.97 196.01 205.30 196.83 164.65 - 107.85 1.33 5982633.23 258848.96 N 70.35317915 W 147.95841685 3943.17 17.08 317.82 3876.33 3924.83 210.07 219.76 211.15 175.48 - 117.43 1.32 5982644.36 258839.73 N 70.35320874 W 147.95849467 3993.17 17.43 315.86 3924.08 3972.58 224.38 234.59 225.79 186.30 - 127.58 1.36 5982655.50 258829.94 N 70.35323829 W 147.95857704 4043.17 18.31 313.77 3971.67 4020.17 239.04 249.93 240.88 197.10 - 138.46 2.18 5982666.65 258819.40 N 70.35326781 W 147.95866543 4093.17 21.61 313.22 4018.66 4067.16 255.22 267.00 257.63 208.85 - 150.85 6.61 5982678.78 258807.40 N 70.35329989 W 147.95876599 4143.17 24.37 313.03 4064.68 4113.18 273.69 286.53 276.82 222.19 - 165.10 5.52 5982692.58 258793.59 N 70.35333635 W 147.95888171 4193.17 26.06 313.25 4109.92 4158.42 293.85 307.83 297.80 236.76 - 180.64 3.39 5982707.64 258778.52 N 70.35337614 W 147.95900790 4243.17 27.77 313.24 4154.50 4203.00 315.28 330.46 320.15 252.26 - 197.13 3.42 5982723.67 258762.55 N 70.35341850 W 147.95914175 4293.17 28.48 312.95 4198.60 4247.10 337.58 354.03 343.46 268.37 - 214.34 1.45 5982740.31 258745.86 N 70.35346249 W 147.95928150 4343.17 30.30 313.05 4242.16 4290.66 360.78 378.57 367.75 285.10 - 232.28 3.64 5982757.62 258728.47 N 70.35350821 W 147.95942 4393.17 31.58 313.41 4285.04 4333.54 385.12 404.27 393.24 302.71 - 251.01 2.59 5982775.82 258710.31 N 70.35355631 W 147.95957. 4443.17 33.20 314.56 4327.26 4375.76 410.59 431.05 419.87 321.31 - 270.28 3.47 5982795.03 258691.66 N 70.35360713 W 147.95973570 4493.17 34.94 315.11 4368.68 4417.18 437.35 459.06 447.78 341.06 - 290.14 3.53 5982815.41 258672.44 N 70.35366108 W 147.95989695 4543.17 36.92 315.33 4409.17 4457.67 465.44 488.40 477.04 361.89 - 310.80 3.97 5982836.89 258652.46 N 70.35371798 W 147.96006474 4593.17 38.22 315.20 4448.79 4497.29 494.64 518.89 507.45 383.54 - 332.26 2.60 5982859.22 258631.71 N 70.35377713 W 147.96023897 4643.17 39.00 314.85 4487.87 4536.37 524.48 550.09 538.57 405.62 - 354.31 1.62 5982881.99 258610.38 N 70.35383743 W 147.96041803 4693.17 39.39 314.78 4526.62 4575.12 554.67 581.69 570.10 427.89 - 376.73 0.79 5982904.97 258588.69 N 70.35389827 W 147.96060004 4743.17 39.03 314.73 4565.36 4613.86 584.85 613.29 601.64 450.14 - 399.17 0.72 5982927.93 258566.98 N 70.35395906 W 147.96078229 4793.17 39.19 314.86 4604.15 4652.65 614.98 644.84 633.12 472.36 - 421.56 0.36 5982950.86 258545.32 N 70.35401977 W 147.96096403 4843.17 39.59 314.96 4642.80 4691.30 645.31 676.56 664.80 494.76 - 444.03 0.81 5982973.98 258523.58 N 70.35408096 W 147.96114650 4893.17 39.55 314.96 4681.34 4729.84 675.76 708.42 696.60 517.27 - 466.57 0.08 5982997.19 258501.78 N 70.35414244 W 147.96132950 4943.17 40.12 315.21 4719.73 4768.23 706.41 740.44 728.59 539.95 - 489.18 1.18 5983020.59 258479.91 N 70.35420440 W 147.96151312 SurveyEditor Ver SP 2.1 Bld( users) 2- 30\ 2- 30/0- 09 \2- 30B/ME- 01 \2- 30B /ME -01 Generated 4/21/2009 2:16 PM Page 2 of 5 • Measured Azimuth Vertical Along Hole NS EW Comments Depth Inclination True Sub -Sea TVD TVD Section Departure Closure True North True North DLS Northing Easting Latitude Longitude (ft ) (deg) (deg) (ft) (ft) (ft ) (ft) (ft) (ft ) (ft) _ (deg/100ft) (ftUS) (ftUS) 4993.17 40.16 315.04 4757.96 4806.46 737.25 772.68 760.79 562.79 - 511.92 0.23 5983044.15 258457.92 N 70.35426680 W 147.96169779 5043.17 40.74 315.17 4796.00 4844.50 768.29 805.12 793.20 585.77 - 534.82 1.17 5983067.86 258435.77 N 70.35432958 W 147.96188371 5093.17 40.86 315.09 4833.85 4882.35 799.56 837.79 825.84 608.93 - 557.87 0.26 5983091.74 258413.48 N 70.35439283 W 147.96207087 5143.17 41.38 314.87 4871.52 4920.02 831.00 870.67 858.69 632.17 - 581.13 1.08 5983115.72 258390.98 N 70.35445632 W 147.96225974 5193.17 41.79 314.62 4908.92 4957.42 862.69 903.86 891.84 655.53 - 604.70 0.88 5983139.82 258368.18 N 70.35452013 W 147.96245114 5243.17 42.14 314.40 4946.10 4994.60 894.58 937.29 925.24 678.97 - 628.54 0.76 5983164.02 258345.10 N 70.35458416 W 147.96264475 5293.17 42.71 314.18 4983.00 5031.50 926.71 971.02 958.93 702.52 - 652.69 1.18 5983188.33 258321.73 N 70.35464850 W 147.96284082 5342.17 42.97 313.95 5018.93 5067.43 958.41 1004.34 992.20 725.70 - 676.63 0.62 5983212.26 258298.54 N 70.35471180 W 147.96303522 5393.17 43.60 313.78 5056.06 5104.56 991.64 1039.31 1027.11 749.93 - 701.84 1.26 5983237.29 258274.13 N 70.35477799 W 147.96323994 5443.17 43.97 313.51 5092.16 5140.66 1024.48 1073.90 1061.66 773.81 - 726.87 0.83 5983261.96 258249.87 N 70.35484321 W 147.96344325 5493.17 44.35 313.39 5128.03 5176.53 1057.50 1108.74 1096.43 797.76 - 752.16 0.78 5983286.72 258225.37 N 70.35490865 W 147.96364860 5543.17 44.78 313.20 5163.65 5212.15 1090.73 1143.82 1131.46 821.82 - 777.70 0.90 5983311.59 258200.62 N 70.35497437 W 147.96385. 5593.17 45.08 312.96 5199.05 5247.55 1124.14 1179.13 1166.71 845.94 - 803.49 0.69 5983336.52 258175.62 N 70.35504026 W 147.96406542 5643.17 45.64 313.12 5234.18 5282.68 1 157.78 1214.71 1202.22 870.22 - 829.49 1.14 5983361.62 258150.41 N 70.35510658 W 147.96427657 5693.17 45.72 313.13 5269.11 5317.61 1191.63 1250.48 1237.94 894.67 - 855.60 0.16 5983386.90 258125.11 N 70.35517338 W 147.96448859 5743.17 46.17 313.24 5303.88 5352.38 1225.64 1286.42 1273.82 919.27 - 881.80 0.91 5983412.33 258099.71 N 70.35524055 W 147.96470136 Tie in Survey 5793.17 46.38 313.25 5338.44 5386.94 1259.86 1322.55 1309.91 944.02 - 908.12 0.42 5983437.91 258074.20 N 70.35530817 W 147.96491511 Top Window (Inc +trend) 5818.00 46.57 313.19 5355.54 5404.04 1276.90 1340.55 1327.89 956.35 - 921.24 0.78 5983450.66 258061.49 N 70.35534185 W 147.96502165 5882.88 49.05 317.10 5399.12 5447.62 1322.90 1388.61 1375.93 990.44 - 955.11 5.88 5983485.81 258028.73 N 70.35543496 W 147.96529669 MWD +IFR +MS 5972.37 51.96 321.44 5456.05 5504.55 1390.23 1457.65 1444.85 1042.77 - 1000.10 4.96 5983539.57 257985.45 N 70.35557792 W 147.96566209 6067.98 54.78 321.49 5513.09 5561.59 1465.66 1534.37 1521.26 1102.79 - 1047.90 2.95 5983601.09 257939.61 N 70.35574186 W 147.96605026 6165.55 56.31 324.55 5568.29 5616.79 1545.11 1614.81 1601.19 1167.05 - 1096.27 3.02 5983666.88 257893.34 N 70.35591741 W 147.96644310 6254.11 57.58 325.82 5616.60 5665.10 1618.81 1689.04 1674.65 1227.99 - 1138.64 1.87 5983729.15 257852.95 N 70.35608387 W 147.96678723 6348.43 58.86 327.61 5666.28 5714.78 1698.65 1769.21 1753.76 1295.02 - 1182.63 2.11 5983797.55 257811.14 N 70.35626696 W 147.96714454 6442.98 59.30 326.50 5714.86 5763.36 1779.45 1850.33 1833.82 1363.09 - 1226.74 1.11 5983867.00 257769.24 N 70.35645289 W 147.96750284 6536.39 59.50 325.42 5762.41 5810.91 1859.41 1930.73 1913.48 1429.71 - 1271.75 1.02 5983935.03 257726.40 N 70.35663488 W 147.96786840 6631.70 60.26 327.15 5810.24 5858.74 1941.43 2013.17 1995.16 1498.28 - 1317.50 1.76 5984005.04 257682.88 N 70.35682219 W 147.96824003 6725.36 63.05 329.16 5854.71 5903.21 2023.67 2095.59 2076.49 1568.30 - 1360.97 3.53 5984076.42 257641.69 N 70.35701346 W 147.96859312 6819.94 64.67 331.84 5896.38 5944.88 2108.53 2180.49 2159.76 1642.20 - 1402.76 3.07 5984151.62 257602.30 N 70.35721531 W 147.96893. 6913.51 64.03 330.45 5936.89 5985.39 2192.87 2264.83 2242.43 1716.07 - 1443.46 1.50 5984226.76 257563.99 N 70.35741711 W 147.96926 7007.14 65.39 329.94 5976.88 6025.38 2277.48 2349.49 2325.78 1789.53 - 1485.54 1.53 5984301.53 257524.30 N 70.35761776 W 147.96960508 7102.01 63.84 330.27 6017.55 6066.05 2363.14 2435.20 2410.28 1863.83 - 1528.26 1.66 5984377.16 257484.00 N 70.35782072 W 147.96995212 7196.72 64.31 330.11 6058.96 6107.46 2448.28 2520.38 2494.32 1937.74 - 1570.61 0.52 5984452.39 257444.05 N 70.35802261 W 147.97029612 7292.14 63.82 329.93 6100.69 6149.19 2534.03 2606.19 2579.10 2012.07 - 1613.49 0.54 5984528.06 257403.59 N 70.35822564 W 147.97064447 7387.25 62.64 329.56 6143.53 6192.03 2618.88 2691.10 2663.11 2085.41 - 1656.27 1.29 5984602.74 257363.19 N 70.35842600 W 147.97099205 7482.21 62.95 328.90 6186.94 6235.44 2703.24 2775.55 2746.83 2157.98 - 1699.47 0.70 5984676.66 257322.34 N 70.35862421 W 147.97134307 7577.49 63.48 328.70 6229.88 6278.38 2788.16 2860.61 2831.27 2230.73 - 1743.54 0.59 5984750.79 257280.64 N 70.35882294 W 147.97170104 7671.57 63.72 328.57 6271.71 6320.21 2872.29 2944.88 2914.99 2302.69 - 1787.40 0.28 5984824.12 257239.12 N 70.35901949 W 147.97205739 7767.40 63.19 328.48 6314.54 6363.04 2957.86 3030.61 3000.21 2375.80 - 1832.16 0.56 5984898.63 257196.74 N 70.35921920 W 147.97242105 7860.91 64.69 329.43 6355.62 6404.12 3041.74 3114.61 3083.67 2447.77 - 1875.47 1.85 5984971.95 257155.76 N 70.35941578 W 147.97277299 7955.83 63.50 330.32 6397.09 6445.59 3127.06 3199.99 3168.37 2521.62 - 1918.33 1.51 5985047.14 257115.31 N 70.35961749 W 147.97312118 SurveyEditor Ver SP 2.1 Bld( users) 2- 30 \2- 30/0- 09 \2- 30B /ME- 01\2- 30B /ME -01 Generated 4/21/2009 2:16 PM Page 3 of 5 ■ • Measured Azimuth Vertical Along Hole NS EW Comments Depth Inclination True Sub -Sea TVD TVD Section Departure Closure True North True North DLS Northing Easting Latitude Longitude (ft ) (deg) _ (deg) (ft ) (ft) (ft ) (ft) (ft) (ft) (ft) (deg/100ft ) (ftUS) (ftUS) 8050.79 62.43 330.08 6440.25 6488.75 3211.60 3284.57 3252.25 2595.02 - 1960.36 1.15 5985121.85 257075.66 N 70.35981798 W 147.97346273 8144.67 62.52 329.88 6483.63 6532.13 3294.80 3367.82 3334.89 2667.10 - 2002.01 0.21 5985195.23 257036.35 N 70.36001488 W 147.97380117 8238.44 62.42 330.50 6526.98 6575.48 3377.91 3450.98 3417.42 2739.25 - 2043.35 0.60 5985268.67 256997.35 N 70.36021195 W 147.97413706 8333.89 62.88 329.72 6570.83 6619.33 3462.64 3535.76 3501.61 2812.75 - 2085.60 0.87 5985343.49 256957.49 N 70.36041272 W 147.97448037 8430.18 63.21 332.24 6614.48 6662.98 3548.45 3621.58 3586.71 2887.80 - 2127.23 2.36 5985419.83 256918.30 N 70.36061771 W 147.97481866 8523.09 63.04 333.83 6656.48 6704.98 3631.31 3704.46 3668.49 2961.66 - 2164.81 1.54 5985494.86 256883.12 N 70.36081946 W 147.97512405 8618.71 63.25 335.81 6699.68 6748.18 3716.51 3789.76 3752.26 3038.86 - 2201.10 1.86 5985573.19 256849.33 N 70.36103032 W 147.97541900 8711.97 64.36 334.80 6740.85 6789.35 3800.04 3873.44 3834.38 3114.88 - 2236.06 1.54 5985650.29 256816.83 N 70.36123799 W 147.97570316 8806.04 63.60 335.13 6782.12 6830.62 3884.47 3957.98 3917.49 3191.47 - 2271.84 0.87 5985727.99 256783.54 N 70.36144720 W 147.97599391 8900.31 63.68 333.60 6823.97 6872.47 3968.86 4042.44 4000.75 3267.62 - 2308.38 1.46 5985805.28 256749.47 N 70.36165520 W 147.97629091 8994.68 64.42 332.89 6865.27 6913.77 4053.69 4127.30 4084.69 3343.39 - 2346.58 1.04 5985882.23 256713.73 N 70.36186216 W 147.976601 9089.51 64.29 331.72 6906.31 6954.81 4139.18 4212.79 4169.49 3419.08 - 2386.31 1.12 5985959.16 256676.46 N 70.36206891 W 147.976924 9183.83 63.00 331.46 6948.18 6996.68 4223.69 4297.30 4253.47 3493.42 - 2426.52 1.39 5986034.75 256638.66 N 70.36227196 W 147.97725110 9278.01 62.99 330.72 6990.95 7039.45 4307.59 4381.21 4336.95 3566.87 - 2467.09 0.70 5986109.47 256600.48 N 70.36247259 W 147.97758079 9373.11 61.36 330.24 7035.34 7083.84 4391.66 4465.31 4420.72 3640.06 - 2508.52 1.77 5986183.95 256561.42 N 70.36267249 W 147.97791757 9466.55 62.06 329.82 7079.62 7128.12 4473.89 4547.59 4502.73 3711.34 - 2549.63 0.85 5986256.51 256522.63 N 70.36286717 W 147.97825164 9561.57 61.82 329.86 7124.32 7172.82 4557.68 4631.44 4586.35 3783.84 - 2591.75 0.26 5986330.32 256482.86 N 70.36306519 W 147.97859405 9654.11 62.30 329.66 7167.68 7216.18 4639.37 4713.20 4667.89 3854.46 - 2632.93 0.55 5986402.23 256443.98 N 70.36325810 W 147.97892870 9748.60 61.63 330.77 7212.09 7260.59 4722.73 4796.60 4751.03 3926.85 - 2674.36 1.26 5986475.91 256404.90 N 70.36345580 W 147.97926546 9844.33 63.06 330.07 7256.52 7305.02 4807.49 4881.39 4835.55 4000.58 - 2716.22 1.63 5986550.95 256365.44 N 70.36365720 W 147.97960570 9938.28 62.12 329.92 7299.77 7348.27 4890.84 4964.79 4918.73 4072.81 - 2757.92 1.01 5986624.48 256326.08 N 70.36385447 W 147.97994471 10034.05 62.74 329.53 7344.10 7392.60 4975.67 5049.69 5003.44 4146.12 - 2800.72 0.74 5986699.13 256285.66 N 70.36405472 W 147.98029262 10128.57 62.75 330.17 7387.38 7435.88 5059.64 5133.71 5087.27 4218.78 - 2842.93 0.60 5986773.11 256245.82 N 70.36425317 W 147.98063567 10224.19 62.10 330.58 7431.65 7480.15 5144.36 5218.47 5171.79 4292.46 - 2884.82 0.78 5986848.09 256206.32 N 70.36445440 W 147.98097626 10318.72 61.99 332.29 7475.96 7524.46 5227.85 5301.97 5254.93 4365.79 - 2924.75 1.60 5986922.67 256168.77 N 70.36465469 W 147.98130082 10413.75 61.91 331.97 7520.65 7569.15 5311.72 5385.84 5338.35 4439.93 - 2963.95 0.31 5986998.03 256131.97 N 70.36485719 W 147.98161955 10509.60 62.57 331.83 7565.29 7613.79 5396.54 5470.65 5422.77 4514.75 - 3003.90 0.70 5987074.09 256094.45 N 70.36506155 W 147.98194434 10602.93 61.64 332.23 7608.96 7657.46 5479.02 5553.14 5504.86 4587.60 - 3042.59 1.07 5987148.14 256058.13 N 70.36526052 W 147.98225887 10697.88 61.78 331.41 7653.96 7702.46 5562.63 5636.75 5588.10 4661.30 - 3082.08 0.77 5987223.07 256021.04 N 70.36546182 W 147.98257 10792.25 62.11 331.17 7698.34 7746.84 5645.90 5720.03 5671.10 4734.34 - 3122.08 0.42 5987297.36 255983.41 N 70.36566131 W 147.98290. 10887.12 61.49 331.54 7743.17 7791.67 5729.51 5803.64 5754.42 4807.72 - 3162.16 0.74 5987371.98 255945.71 N 70.36586172 W 147.98323101 10983.43 62.16 331.22 7788.65 7837.15 5814.40 5888.53 5839.04 4882.24 - 3202.83 0.75 5987447.77 255907.46 N 70.36606527 W 147.98356164 11076.66 62.38 332.42 7832.03 7880.53 5896.92 5971.06 5921.24 4954.98 - 3241.80 1.16 5987521.73 255870.85 N 70.36626394 W 147.98387849 11171.15 62.46 331.68 7875.78 7924.28 5980.67 6054.81 6004.65 5028.96 - 3281.05 0.70 5987596.93 255834.00 N 70.36646600 W 147.98419767 11266.14 62.91 331.66 7919.37 7967.87 6065.07 6139.21 6088.75 5103.25 - 3321.10 0.47 5987672.47 255796.36 N 70.36666891 W 147.98452333 11360.29 63.35 331.84 7961.92 8010.42 6149.05 6223.19 6172.45 5177.23 - 3360.86 0.50 5987747.69 255759.01 N 70.36687097 W 147.98484656 11454.08 63.90 331.24 8003.58 8052.08 6233.07 6307.22 6256.21 5251.10 - 3400.90 0.82 5987822.81 255721.37 N 70.36707273 W 147.98517216 11548.06 63.66 329.73 8045.11 8093.61 6317.35 6391.53 6340.37 5324.47 - 3442.43 1.46 5987897.47 255682.22 N 70.36727310 W 147.98550987 11643.02 63.88 329.14 8087.08 8135.58 6402.45 6476.71 6425.48 5397.81 - 3485.75 0.60 5987972.17 255641.29 N 70.36747342 W 147.98586208 I 11736.66 62.04 329.93 8129.65 8178.15 6485.77 6560.11 6508.81 5469.70 - 3528.04 2.10 5988045.37 255601.33 N 70.36766974 W 147.98620594 SurveyEditor Ver SP 2.1 Bld( users) 2- 30\2 -30/0- 09\2- 30B/ME- 01 \2- 30B /ME -01 Generated 4/21/2009 2:16 PM Page 4 of 5 • Measured Azimuth Vertical Along Hole NS EW i Comments Depth Inclination True Sub -Sea TVD TVD Section Departure Closure True North True North DLS Northing Easting Latitude Longitude (ft) (deg) (deg) (ft) (ft) (ft) (ft ) (ft) (ft ) (ft) (deg/100ft ) (ftUS) (ftUS) 11830.25 59.40 330.99 8175.42 8223.92 6567.36 6641.73 6590.30 5540.71 - 3568.29 2.99 5988117.64 255563.39 N 70.36786368 W 147.98653326 11925.24 55.82 331.77 8226.29 8274.79 6647.56 6721.93 6670.29 5611.10 - 3606.71 3.83 5988189.23 255527.25 N 70.36805594 W 147.98684573 12018.33 54.12 331.01 8279.73 8328.23 6723.78 6798.16 6746.32 5678.02 - 3643.21 1.94 5988257.28 255492.93 N 70.36823870 W 147.98714251 12113.26 52.23 331.49 8336.62 8385.12 6799.75 6874.14 6822.13 5744.64 - 3679.76 2.03 5988325.04 255458.54 N 70.36842064 W 147.98743975 12206.50 48.17 331.58 8396.29 8444.79 6871.37 6945.76 6893.56 5807.60 - 3713.89 4.35 5988389.06 255426.45 N 70.36859260 W 147.98771738 12302.23 45.75 330.72 8461.63 8510.13 6941.32 7015.72 6963.37 5868.88 - 3747.64 2.61 5988451.40 255394.69 N 70.36875997 W 147.98799184 12397.01 43.01 330.35 8529.36 8577.86 7007.59 7082.00 7029.56 5926.59 - 3780.24 2.90 5988510.13 255363.97 N 70.36891759 W 147.98825696 12490.88 40.17 328.77 8599.56 8648.06 7069.83 7144.31 7091.82 5980.32 - 3811.79 3.22 5988564.83 255334.17 N 70.36906432 W 147.98851348 12584.78 38.12 329.37 8672.38 8720.88 7129.03 7203.58 7151.07 6031.16 - 3842.26 2.22 5988616.63 255305.35 N 70.36920317 W 147.98876129 12680.13 35.42 331.33 8748.76 8797.26 7186.07 7260.65 7208.07 6080.74 - 3870.51 3.09 5988667.09 255278.70 N 70.36933857 W 147.98899109 12772.44 31.63 329.27 8825.70 8874.20 7237.01 7311.62 7258.97 6125.03 - 3895.73 4.29 5988712.17 255254.93 N 70.36945954 W 147.98919615 12866.98 28.52 329.77 8907.50 8956.00 7284.34 7358.99 7306.32 6165.85 - 3919.76 3.30 5988753.74 255232.22 N 70.36957102 W 147.98939 12961.06 26.29 331.00 8991.02 9039.52 7327.62 7402.29 7349.56 6203.48 - 3941.18 2.45 5988792.04 255212.03 N 70.36967380 W 147.98956 13055.85 23.50 331.21 9076.99 9125.49 7367.51 7442.19 7389.39 6238.41 - 3960.46 2.94 5988827.57 255193.88 N 70.36976919 W 147.98972261 13151.23 20.67 331.92 9165.37 9213.87 7403.37 7478.04 7425.16 6269.94 - 3977.54 2.98 5988859.63 255177.82 N 70.36985529 W 147.98986158 13244.35 19.48 332.02 9252.83 9301.33 7435.33 7510.01 7457.03 6298.15 - 3992.56 1.28 5988888.31 255163.71 N 70.36993235 W 147.98998376 13338.97 19.06 332.74 9342.15 9390.65 7466.56 7541.23 7488.15 6325.82 - 4007.04 0.51 5988916.43 255150.13 N 70.37000791 W 147.99010152 13433.57 17.56 331.53 9431.95 9480.45 7496.27 7570.95 7517.77 6352.09 - 4020.92 1.64 5988943.13 255137.11 N 70.37007967 W 147.99021441 13527.93 18.25 330.42 9521.74 9570.24 7525.28 7599.96 7546.73 6377.46 - 4035.00 0.82 5988968.94 255123.85 N 70.37014894 W 147.99032893 13622.67 18.87 331.31 9611.56 9660.06 7555.43 7630.11 7576.84 6403.80 - 4049.68 0.72 5988995.74 255110.03 N 70.37022088 W 147.99044831 13683.02 18.21 330.76 9668.77 9717.27 7574.61 7649.30 7596.00 6420.59 - 4058.97 1.13 5989012.81 255101.29 N 70.37026673 W 147.99052389 13778.97 16.92 330.83 9760.25 9808.75 7603.56 7678.26 7624.91 6445.86 - 4073.10 1.34 5989038.53 255087.98 N 70.37033576 W 147.99063881 13873.78 16.96 331.37 9850.94 9899.44 7631.18 7705.88 7652.49 6470.05 - 4086.45 0.17 5989063.13 255075.41 N 70.37040181 W 147.99074740 13966.55 16.69 331.53 9939.74 9988.24 7658.03 7732.74 7679.28 6493.63 - 4099.28 0.30 5989087.12 255063.34 N 70.37046623 W 147.99085179 14063.01 16.58 331.11 10032.17 10080.67 7685.65 7760.35 7706.84 6517.86 - 4112.53 0.17 5989111.76 255050.88 N 70.37053239 W 147.99095959 Last Survey 14156.61 16.59 330.93 10121.87 10170.37 7712.36 7787.07 7733.52 6541.23 - 4125.48 0.06 5989135.53 255038.69 N 70.37059622 W 147.99106488 TO (Projected) 14207.00 16.59 330.93 10170.16 10218.66 7726.74 7801.45 7747.88 6553.81 - 4132.47 0.00 5989148.32 255032.11 N 70.37063056 W 147.99112174 Survey Type: Definitive Survey NOTES: GYD CT DMS - ( Gyrodata - cont. drillpipe m/s -- Gyrodata pump -down multishot surveys with continuous tool (RGS -CT) in drill - pipe.) INC +Trend - ( Inclinometer + known azi trend -- Inclination only surveys in near - vertical hole -where formation dip and experience enables direction of drift to be predicted. Replaces ex -BP "Inclinometer (azimuth in known quadrant)" model. ) MWD + IFR + MS - ( In -field referenced MWD with mult- station analysis and correction applied in post - processing. Assumes a BHA sag corn Survey Tool Type Borehole -> Survey Legal Description: Northing (Y) fftUSl Eastinq (X) fftUSl Surface : 3326 FSL 2255 FEL S36 T12N R16E UM 5982465.20 258951.45 BHL : 4599 FSL 1106 FEL S26 T12N R16E UM 5989148.32 255032.11 SurveyEditor Ver SP 2.1 Bld( users) 2- 30\2 -30/0- 09\2- 30B /ME- 01 \2- 30B /ME -01 Generated 4/21/2009 2:16 PM Page 5 of 5 I TREE : 4- 1/16 CIW = MCEVOY " W • E SAFSNOTES: ** *CHROME TUBING * ** ACTUATOR = BAKER END 2.3 O R V ORIGINAL WELLBORE (2 - 30) NOT SHOWN ON ORIG KB. ELEV = 56' DIAGRAM ORIG BF. ELEV = 21.3' KOP Max Angle = 65° @ 7007' 1512' H4 -1/2" HES HXO SSSV NIP, ID = 3.813" Datum MD = 14029' Datum TVD = 10000' SS III 1512' H4 -1/2" FRAC SLEEVE, ID = 2.625" (04/12/09) I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13 -3/8" CSG, 68 #, NT80, H 2709' 1 I 5 3543 3537 11 KBG -2 DMY SBK 0 04/10/09 BTRS, ID = 12.415" 4 6717 5899 63 KBG -2 DMY BEK 0 04/10/09 3 10399 7562 62 KBG -2 DMY SBK 0 03/15/09 Minimum ID = 3.725" @ 13652' 2 12610 8741 37 KBG -2 DMY SBK 0 03/15/09 1 13392 9441 18 KBG -2 SPMG SBK 0 04/10/09 4 -1/2" HES XN NIPPLE 1 5672' I- 9 -5/8" x 7" BKR 7XP LT PKR, ID = 6.22" 7" CSG, 26#, L -80, TCII, ID = 6.276" H 568T I w /TIEBACK SEAL ASSY & FLEXLOCK LNR HGR 1 9 -5/8" MILLOUT WINDOW (230B): 5818' - 5834' 9 -5/8" CSG, 47 #, NT80S, BTC, ID = 8.681" I--I 5818' I TOP OF 9 -5/8" WHIPSTOCK H 5818' I/ TOP OF 9 -5/8" BRIDGE PLUG I- 5841' I--- 7" TUBING STUB (02/22/09) l-L 5880' M0-■11111 MI 9 -5/8" MILLOUT WINDOW (2-30A): 6130' - SWA 2∎•••••••∎ _ 1358T H4 - 1/2" HES XNIP, ID = 3.813" I .tl : 4. 4. 4. 4 k III A I g 13608' I--17" x 4 -1/2" BKR S -3 PKR, ID = 3.875" 1 eAven. PERFORATION SUMMARY REF LOG: t ' ' 13631' 1-14 -1/2" HES X NIP, ID = 3.813" 1 ANGLE AT TOP PERF: 17° @ 13790' Mehl Note: Refer to Production DB for historical pert data SPF INTERVAL Opn/Sqz DATE 13652' 1-14-1/2" HES XN NIP, ID = 3.725" I 3 -3/8-3/8 " 6 13790 - 13854 0 04/05/09 ...1�•..'.'4' • ...NON. , ■ 13674' 1 -14 -1/2" WLEG, ID = 4.00"1 4 -1/2" TBG, 12.6 #, 13 -CR, VAM TOP, .0152 bpf, ID = 3.920" H 13674' PBTDI - 1 14104' I 11 1 7" LNR, 26 #, 13CR -80, HYD, ID = 6.276" H 14193' ∎••••••• DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT MPI UNIT 02/12/92 ORIGINAL COMPLETION 04/12/09 SWC /SV GLV C/O (04/10/09) WELL: 2 -30B / ME -01 01/20/99 SIDETRACK (230A/EI01) 04/12/09 SWC /SV SET FRAC SLEEVE PERMIT No: 2081870 03/17/09 D14 SIDETRACK (2-30B/ME-01) API No: 50- 029 - 22228 -02 03/23/09 DAJ /SV FINAL DRAFT CORRECTIONS SEC 36, T12N, R16E, 1953 FNL, 2245 FEL 04/06/09 DAV /SV CORRECTION 04/08/09 RRK /SV ADPERF (04/05/09) BP Exploration (Alaska) rr, „:„ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact Joe Lastufka at (907)564 -4091 Delivery Contents END OF WELL REPORT API - 500292222802 S/W NAME: 2- 30B /ME -01 /1 if", i ' ase Sign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center DNR Kristin Dirks AOGCC Christine Mahnken )() - (5 Petrotechnical Data Center LR2 -1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 t • • 1 )�) �� = SARAN PALlN, GOVERNOR ALASKA OIL AND GAS 333 W 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. CO 202.043 (Endicott Oil Pool, Endicott Field) ADMINISTRATIVE APPROVAL NO. CO 275.001 (Alapah and Ivishak Oil Pools, Endicott Field) ADMINISTRATIVE APPROVAL NO. CO 449.001 (Eider Oil Pool, Endicott Field) Mr. R. L. Skillern 0 v ( Z — 1 Senior Landman BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Surface Commingling of Production from Proposed Endicott Field Well 2- 30B /ME -01 with Production from Defined Endicott Field Oil Pools Dear Mr. Skillern: The Alaska Oil and Gas Conservation Commission (Commission) received your letter, dated November 20, 2008, requesting approval to commingle production on the surface from the proposed Endicott Field Well 2- 30B /ME -01 with production from the Eider, Ivishak, Alapah, and Endicott Oil Pools (i.e., "defined Endicott Field oil pools "). The Commission GRANTS your request subject to certain conditions as listed below. Proposed Well 2- 30B /ME -01 is on lease ADL 34633 (Tract 13), which is within the Endicott Field, but is not part of any defined Endicott Field oil pool. Based on seismic information, proposed Well 2- 30B /ME- 01 production will not drain those oil pools. BP Exploration (Alaska) Inc. (BPXA) has requested that Well 2- 30B /ME -01 be allocated on a daily basis using the same methodology employed for wells in the Eider Oil Pool. Well 2- 30B /ME -0I allocated production will be based upon a minimum of two well tests per month. BPXA proposes that the allocation factor be fixed at 1.0 (i.e., it will not be adjusted for discrepancies between measurements of total Endicott Field oil production derived from well tests and from the Lease Automated Custody Transfer (LACT) meter). The Commission grants BPXA's request to commingle production on the surface from the proposed Endicott Field Well 2- 30B /ME -01 with production from the defined Endicott Field oil pools prior to custody transfer. This approval is conditioned upon the following: 1. Unless the Commission otherwise requires, production from Well 2-30B/ME-0 I will be determined through well tests conducted at least twice per month at a stabilized flow rate lasting more than four hours. 2. Unless the Commission otherwise requires, production from Well 2- 30B /ME -01 will be allocated on a daily basis using the same methodology employed for wells in the Eider Oil Pool, with a meter allocation factor fixed at 1.0. The operator shall provide the Commission with a written well test and allocation report at the end of 1 40 S Mr. L. R. Skillern January 22, 2009 Page 2 of 2 each calendar year. 4. Within one year after the start of production from Well 2- 30B /ME -01, the operator shall (1) provide the Commission a written report with all reasonably available evidence regarding whether the well is in communication with any defined Endicott Field oil pools, and (2) apply to the Commission to include the well within an already defined Endicott Field pool or within a new Endicott Field pool. 5. Unless notice and a public hearing are required, upon proper application or its own motion, the Commission may administratively amend this order as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in an increased risk of fluid movement into freshwater. ENTERED at Anchorage, Alaska, and dated January 009. N ,,�.S i?iL m r F?' Daniel T. Seamount, Jr., Chair 1 )1 %; , 4' ' ( ,.. S /6'2.0.€4,47,2"...._ Z 0 Ni Cathy P. , oerster, Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31,05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsid- eration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for re- consideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Fail- ure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days af- ter the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission oth- erwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(6), "[tlhe questions reviewed on ap- peal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. 2 -30 A Sundry and 2 -30B Dril],g Permit Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, January 15, 2009 8:30 AM To: 'Johnson, David A. (Fairweather)' Subject: RE: 2 -30 A Sundry and 2 -30B Drilling Permit Dave, I was looking to file my reply and as I searched determined that the wells you refer to are at Endicott. It is important to make sure when you send a message regarding wells that the well name is complete. In this case the full names are 2- 30A /E102 (198 -188) and 2- 30B /ME -01 (208 -187). Hope you get the rig out there soon. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Wednesday, January 14, 2009 1:03 PM To: 'Johnson, David A. (Fairweather)' Subject: RE: 2 -30 A Sundry and 2 -30B Drilling Permit Thanks Dave. This is not an issue, except in the case where you might like to have the shear capability. From: Johnson, David A. (Fairweather) [mailto:David.A.Johnson @bp.com] Sent: Wednesday, January 14, 2009 1:01 PM To: Maunder, Thomas E (DOA) Subject: 2 -30 A Sundry and 2 -30B Drilling Permit Tom, On the Sundry Notice to decomplete 2 -30A ( #308 -436) and on the permit to redrill 2 -30B ( #208 -187), inadvertently showed Doyon 14 as having blind /shear rams. Doyon 14 has blind rams, not blind /shear. (I had become to accustomed to working Northstar.) The same problem occurred on the MPF -96 permit and Jim Regg was notified in your absence. 1 would appreciate you noting the change. Dave «Johnson, David A. ( Fairweather) (john23 @BP.com).vcf» 1/15/2009 1 t _ n LA SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Dan Kara Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519 -6612 Re: Endicott Field, Undefined Oil Pool, END 2- 30B /ME -01 BP Exploration Alaska Inc. Permit No: 208 -187 Surface Location: 3327' FSL, 2245' FEL, SEC. 36, T12N, R16E, UM Bottomhole Location: 4704' FSL, 1069' FEL, SEC. 26, T12N, R16E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, 4 2 69-/-7,------ Cathy •. Foerster Commissioner DATED this eay of December, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ,..fey' ALAS OIL AND GAS CONSERVATION COMMON /p?•3-O PERMIT TO DRILL 20 AAC 25.005 " 1,-) 1 a. Type of work 1 b. Current Well Class ❑ Exploratory ❑ Development Gas 1c. ecify if well is proposed for: ❑ Drill ® Redrill ❑ Service ❑ Multiple Zone ILI Coalbed Methane ❑ Gas Hydrates ❑ Re -Entry ❑ Stratigraphic Test ® Development Oil ❑ Single Zone ❑ Shale Gas 2. Operator Name: 5. Bond: Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 END 2 - 30B /ME - 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 14164' TVD 10134' Endicott Field / Undefined 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 034633 3327' FSL, 2245' FEL, SEC. 36, T12N, R16E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4570' FSL, 998' FEL, SEC. 26, T12N, R16E, UM January 15, 2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4704' FSL, 1069' FEL, SEC. 26, T12N, R16E, UM 2560 578' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Plan 15. Distance to Nearest Well Within Pool: Surface: x- 258962 y- 5982465 Zone -ASP3 (Height above GL): 48.8 feet None 16. Deviated Wells: Kickoff Depth: 5850 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 63 degrees _ Downhole: 4921 Surface: 3907 18. Casino Proaram: Soecifications Too - Settina Depth - Bottom Quantity of Cement. c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8 -1/2" 7" 26# L -80 Hydril 521 7289' 5700' 5564' 12989' 9011' (See Below) 8 -1/2" 7" 26# 13Cr80 Hydril 521 1175' 12989' 9011' 14164' 10134' 1213 cu ft LiteCrete. 275 cu ft Class 'G' Tieback 7" 26# L -80 TCII 5700' Surface Surface 5700' 5564' 84 cu ft Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re - entry Operations) Total Depth MD (ft): Total Depth TVD (ft):I Plugs (measured): !Effective Depth MD (ft): 'Effective Depth TVD (ft):I Junk (measured): 20885' 1018 ' 15668' 20684' 10121' 18300' Casing Length Size Cement Volume MD TVD Conductor / Structural 131' 30" Drive 131' 131' Surface 2709' 13 -3/8" 2025 cu ft PF 'E'. 179 cu ft PF 2709' 2708' Intermediate 6398' 9-5/8" 2784 cu ft Class 'G' 6398' 5795' Production 15828' 7" 471 cu ft Class 'G' 15865' 9538' Liner 5076' 4 -1/2" 604 cu ft Class 'G' 15699' - 20775' 9470' - 10149' Perforation Depth MD (ft): Below Plug: 16285' - 20675' Perforation Depth TVD (ft): 9583' - 10118' 20. Attachments ❑ Filing Fee, $100 ❑ BOP Sketch 0 Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ❑ Diverter Sketch ❑ Seabed Report Drilling Fluid Program 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certi hat the foregoing is true and correct. Contact Dave Johnson, 564 - 4171 Printed e tan Kar- Title Engineering Team Leader —i Prepared By Name/Number: Signatu , /, ' - L�2 � � Phone 564-5667 Date 0 Terrie Hubble, 564 - 4628 Commission Use Only Permit To Drill API Number: Permit Approval See cover letter for Number:,'?0818p 50 Date: It - / 5-OR other reauirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Er It-1Q)0 ,; , re), v-L \ L .=,\. Samples Req'd: Oyes Mud Log Req'd: 0 / Yes L ' No H Measures: Yes ❑ No Directional Survey Req'd: u' Yes ❑ No COO v, i �`.�� c��.iN.►kvt V �.*, it � Other: / Z _ /S , , p PPR ED BY THE MO Date (�� COMMISSIONER COMISSIN Form 10-401 Revised 12/2005 Submit In Duplicate • • � bp November 25 2008 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Endicott 2- 30B /ME -01 Permit to Drill Mr. Maunder: Well 2- 30B /ME -01 is currently scheduled to be drilled by Doyon 14 on February 3rd, 2009. Well 2- 30A/EI -02 will be plug and abandoned and used as the donor well. Please note that this spud date could be advanced early depending on ice road and rig scheduling. Maximum anticipated surface pressure from the Ivishak with a full column of gas from TD to surface is 3,907 psi. We will be utilizing Doyon 14's 5000 psi four preventer stack (3 rams and an annular). The BOPs will be tested to 4000 psi. All wells passed the major risk classification with the exception 2- 30A/EI -02 at KOP. Please find attached the 2- 30B /ME -01 Well Plan Summary, directional plan and proposed completion diagram. If you have any questions or require any additional information, please contact the undersigned at 564 -4171, or Dan Kara at 564 -5803. Sinc- - , 411, r‘ Dave Johnson Drilling Engineer BPXA / ACT • • � bp Well Name: 2- 3OB /ME -01 Endicott Sag /lvishak Producer Drilling and Completion Plan Summary 1 Type of Well: 1 Sag /lvishak Producer Surface Location: 3,327' FSL and 2,246' FEL Section 36, T12N, R16E UM E = 258,960.4' N = 5,982,464.78' T1 — Near Top of Sag 4,570' FSL and 998' FEL 13,748' MD Section 26, T12N, R16E UM E = 255,138.63' N = 5,989,115.43' Z = 9,655' TVDss At TD 14,164' TMD 4,704' FSL and 1,069' FEL Section 26, T12N, R16E UM E = 255,072.03' N = 5,989,251.00' Z = 10,085' TVDss Distance to Nearest Property Line 578' South of boundary lease line (ADL034633) Distance to Nearest Well in Pool No Other Wells In Pool 2- 30/0 -09 (P &A, 1490 feet to SW) Nearest Wells 2- 24/M12 (Shut in injector, 2200 feet to SE) SD -08 (P &A, 7480 feet West) SD- 09/5 -03 (Injector, 6010 feet East) AFE Number: 1 Rig: 1 Doyon 14 Estimated Start Date: 1 2/3/2009 Rig days to complete: 1 45 MD: 1 14,164' I TVD: 1 10,134' 1 Max Inc:1 63 KOP: 1 5850' 1 KBE:1 48.8' Well Design: "S- Curve ", Producer — Window in Intermediate Casing Objective: Sag/Ivishak 1 0 Formation Markers: Formation Tops(TVDss) and Estimated Pore Pressures Estimated Depths Tops Hydrocarbon Estimated Bearing Formation TVDss TVDrkb MDrkb Y/N Pore Press. (Psi) (ppg) KOP in SV Sands -5379 5,428 5,850 No 2420 8.7 Ugnu -5823 5,872 6690 No 2620 8.7 CM3 -7776 7,825 10,848 No 3499 8.7 Top Tuff Marker -9140 9,189 13,159 No 4204 8.8 Top HRZ -9410 9,459 13,446 No 4470 9.1 Base HRZ -9620 9,669 13,669 No 4695 9.4 TSGR -9665 9,714 13,717 Yes 4717 9.4 TSHU -9745 9,794 13,802 No 4756 9.4 TSAD -9815 9,864 13,877 Yes 4790 9.4 TKVK -10005 10,054 14,079 No 4882 9.4 Total Depth -10085 10,134 14,164 No 4921 9.4 TLSB -10100 10,149 14,200 Possible 4929 9.4 Evaluation Program 8 -1/2" Section From KOP to Base HRZ Open Hole: DIR/GR/RES /PWD I FR/CASAN DRA Mudloggers 8 -1/2" Section Base HRZ to TD Open Hole: DIR/GR/RES /PWD Neutron /Density GeoTap (pressure samples) IFR/CASANDRA Mudloggers Cased Hole: USIT across Sag /Ivishak interval Mud Program: 8 -1/2" Hole KOP to 200' above HRZ LSND Density (ppg) PV YP pH API Filtrate MBT 9.1 —9.5 10 -20 25 -30 9.0 -9.5 NC -8.0 <20 8 -1/2" Hole from HRZ to TD LSND w/ Shale Inhibitors Density (ppg) PV YP pH API Filtrate Chlorides 10.0 -10.5 10 -20 20 -30 9.0 -9.5 4.0 -6.0 <20 2 Present Casing ubing Hole Csg / Wt/Ft Grade Conn Length Top Bottom Size Tbg MD / TVD MD / TVD O.D. 30" Drive Pipe Welded GL 131' / 131' 17 -1/2" 13 -3/8" 68# NT80 BTC 2,709' 0' 2,709' / 2,708' 12 -1/4" 9 -5/8" 47# NT80S NSCC 6,398' 0' 6,398' / 5,795' 9 -5/8" Section Milled from 6,398' to 6,494'. 8 -1/2" 7" 29# L -80 Hydril 563 15,865' 0 15865'/9,538' 6" 4 -1/2" 12.6# L -80 SLHT 5,076 15,699'/9,470' 20,775'/10149' TBG 4 -1/2 12.6# L -80 IBM 15,702' 0 15,702'/9,472' New Casing/Tubing Program Hole Csg / Wt/Ft Grade Conn Length Top Bottom Size Tbg MD /TVD MD /TVD O.D. 30" Drive Pipe Welded 77' GL 131' / 131' 17 -1/2" 13 -3/8" 68# NT80 BTC 2,709' 0' 2,709' / 2,708' 12 -1/4" 9 -5/8" 47# NT80S NSCC 5,850' 0' 5,850' / 5,428' 9 -5/8" Top of Window Section at 5850' MD. 8 -1/2" 7" 26# L -80 Hydril 521 7,289' 5,700'/5,564' 12,989'/9,011' Liner 7" 26# 13Cr -80 Hydril 521 1,175' 12,989'/9,011' 14,164'/10,134' 8 -1/2" 7" 26# L -80 TCII 5,700' 0 5,700'/5,564' Tieback TBG 4 -1/2 12.6# 13Cr -80 VamTop 13,650' 0 13,650'/9,650' Cement Program: Casing Size 7 ", 26 #, L- 80/13Cr -80, Hydril 521 Liner from 5,700 to 14,189' MD Lead: From 12,742' (1000' above Sag) to 200' above liner top at 5,700' plus 30% excess of 6,542' open hole + 150' of liner lap + Basis 200' of 5" DP X 9 -5/8" Casing Tail: From 14,189' TD to 12,742' MD (500' above Sag) plus 40% excess of 1,447' open hole Total Cement Spacer 50 bbl of MudPush Volume: 265 bbl p Lead 216 bbls, 514 sks, 11.8 ppg LiteCrete — 2.36 cuft/sk Tail 49 bbls, 237 sks, 15.8 lb/gal Class G — 1.16 cuft/sk Temp BHST 210 ° Fat 10,139' TVD 3 Casing Size 7 ", 26 #, L -80, TCII Tie -back from Surface to 5,700' MD Basis 15% Tail cement = 500' MD. Total Cement Spacer 50 bbl of MudPush Volume: 15 bbl p Tail 15 bbl, 71 sx "G" mixed at 15.8 lb/gal & 1.16 ft3 /sx Temp BHST 114 F at 5560' TVD Well Control: Equipment will be installed that is capable of handling maximum potential surface pressures. (Schematics are on file with the AOGCC and MMS.) Independent gas and H2S detectors will be installed. ■ 5000 psi working pressure pipe rams (2) ■ Blind /shear rams ■ Annular preventer Based upon the calculations below, BOP equipment will be tested to 4000 psi. Production hole: • Maximum anticipated BHP: 4,921 psi at 10,139' TVD at total depth • Maximum surface pressure: 3,907 psi at (Based on a full column of gas at 0.1 psi /ft) • Integrity tests: FIT to 11.5 lb/gal after milling window plus 20' of new hole. • Kick tolerance: 92 bbl with 10.0 lb/gal mud at the 9 -5/8" window. • Planned completion fluid: Seawater with diesel cap. • Casing/Tubing Test 4000 psi 4 • • Drilling Hazards & Contingencies: Lost Circulation /Breathing • Lost circulation is not expected in the Sag or Ivishak formations unless a sub - seismic fault is encountered. • Well bore breathing may be encountered after weighting up the mud to drill the HRZ. No cement is expected out side of the window and there may be hydraulic communication to shallow permeable sands. Follow good hole cleaning practices, minimize ECD's, and minimize surge pressures to mitigate the chance of breathing. Stuck Pipe • Endicott has a history of stuck pipe events both while drilling and running casing. Follow good hole cleaning, and tripping practices. • Minimize the time the drill string and casing are stationary across permeable zones to avoid differential sticking. Expected Pressures • The Sag and Ivishak formations are anticipated to be near original pressure of 9.4 ppg ppg. Pad Data Sheet • Please Read the MPI Pad Data Sheet thoroughly. Hydrocarbons • Hydrocarbons are expected to be encountered only in the Sag and Ivishak formations. Faults • This 2 -30B well trajectory will not cross any faults visible on seismic. Small scale sub - seismic faults could exist which could cause lost circulation in the Sag River & Ivishak intervals. Hydrogen Sulfide • The Endicott Main Production Island is an H site. Standard Operating Procedures for H2S should be followed at all times. Maximum H recorded on MPI is 1300 ppm on 2/14/07. Recent H data from the pad is as follows: Closest Wells at Surface Recent Date Highest Date Well Name H2S H2S #1 2- 28B/0 -19 195 10/13/2008 350 9/21/2006 #2 2 -32 / SN -03 200 10/27/2008 400 1/4/2008 #3 2- 26/N -14 210 10/23/2008 220 2/13/2008 #4 2- 34/P -14 N/A N/A N/A N/A #5 2- 30A/EI -02 3 5/10/2007 200 5/27/2005 Closest Wells at BHL Recent Date Highest Date Well Name H2S H2S #1 2 -56A / E1-01 150 11/13/2007 770 10/31/2005 #2 5- 03 /SD -09 N/A N/A N/A N/A #3 2- 20/L -15 110 11/2/2008 390 9/16/2008 #4 2- 22/L -14 N/A N/A N/A N/A N/A = Injector Readings Not Available • Appropriate precautions will be employed while drilling (i.e.: wind socks, H detectors, etc.) Anti - collision Issues • All wells passed the major risk classification with the exception of the 2 -30 and 2 -30A wellbores at kick- off. 5 • 0 DRILL & COMPLETION PROCEDURE Pre -Riq Operations - For Information Covered by Sundry Notice 1. PPPOT Tubing and Casing. 2. Function test casing and tubing LDS. Back out to ensure full movement as the 9 5/8" packoff will be changed during the rig work and any problem LDS need to be identified early. 3. Pull SSSV or plug if installed. 4. Pull Tail pipe plug. Acquire memory Static BHP survey. 5. Dummy off any open GLMs. 6. Perform injectivity test. Monitor and record IA and OA pressures during pumping operation. 7. Through tubing cement squeeze perforations with 15.8 ppg cement slurry. Final cement volume should be determined by injectivity test. Minimum cement volume should be sufficient to cover perforations and bring cement to packer at 15,645' TMD. This requires a minimum volume of 22.4 BBLS to fill the liner and tubing. Desired volume is 30 BBLS of cement slurry. (Squeeze 2 to 5 BBLS into perfs and leave excess cement in tubing. 8. Run wireline drift tubing and tag TOC. Pressure test tubing to 2000 psi. 9. Jet cut tubing 500' above TOC. 10. Circulate the tubing and IA to 9.1 ppg NaCI brine. Freeze protect tubing and IA to 200' with diesel. 11. Install BPV. 12. Remove gas lift and production flow lines, remove well house from END 2 -26, 2 -28, 2 -30, 2 -32 and 2 -34. Prepare the pad for Doyon 14. Drilling Riq: 1. MIRU Doyon 14. Circulate out diesel freeze protect through tubing cut. Install TWC. 2. ND Tree. NU and test BOPE. 3. Pull and LD 4'h" tubing from pre rig tubing cut. 4. Run bit and scraper to +/- 6600' MD. 5. Run and set 7" BP at 6500' MD. 6. Mechanically cut the 7" casing at 6380' ( +/- 20' inside the 9 -5/8" casing. 7. Circulate out OA freeze protect, pull and lay down 7" casing. 8. MU milling BHA. RIH PU DP to 6,000'. 9. RU Eline. Run USIT log in corrosion mode to evaluate the condition of the 9 5/8" casing from 6000' to surface. Note: The completion schematic showed the top of the milled section at 6130' MD. The daily drilling reports showed milling the section from 6398' to 6494' MD 10. Set a cement retainer at depth as determined by USIT log. Set to avoid milling a collar and to ensure KO in a clean sand. KOP +/- 5,850' TMD. Cement retainer estimated at 5,872' MD. 11. Stab into retainer and establish an injection rate. Monitor and record OOA pressures during pumping operation. 12. Cement squeeze base of 9 -5/8" with 15.8 ppg cement slurry. Final cement volume should be determined by injectivity test. Minimum volume should be 47.5 BBLS (230 sks) to cover 526' from the cement retainer to the base of the 9 -5/8" casing plus 200' of 7" casing X 8 -1/2" hole plus 100% excess of open hole. If a good injection rate is established, the base of the 9 -5/8" casing will be squeezed with 90 BBLS (435 sks) of 15.8 ppg cement slurry. End of Sundry Notice 6 Drilling Permit: • 0 13. MU whipstock. RIH with stands, set whipstock, mill window, and drill 20' of new formation. Perform FIT test. 14. MU 8'h" drilling assembly and directionally drill surface hole to an estimated total depth of 14,189' MD / 10,139' TVD. 15. Run and cement the 7 ", 26 #, Hyd 521, 13Cr / L -80 liner. 16. Run 7" 26# L -80 TCII tie -back and cement a minimum of 500'. Top of cement will be determined by USIT log. 17. MU cleanout BHA. Clean out 7" casing to PBTD. LD DP. 18. MU 4 - 12.6 #, 13Cr -80, Vam Top completion assembly and RIH. See completion schematic for details. Land tubing hanger and run in lockdown screws. 19. Reverse in brine with corrosion inhibitor to protect the annulus down to the packer. 20. Drop RHC ball and rod and set packer. Test tubing to 4,000 psi and annulus to 4,000 psi. Shear DCK valve. 21. Install two -way check and test to 1,000 psi from below. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 22. Pull two -way check. Freeze protect the well to 200' TVD. 23. Install BPV. Secure the well. Rig down and move off. Post -Rig: 1. RU slick line unit. Drift & Tag run to PBTD. RD slick line unit. 2. MIRU slickline. Pull the ball and rod / RHC plug. 3. Pull out DCK shear valve and install GLV in all of the other mandrels. 4. Perforate well as determined from logs. 5. Put the well on production. 7 by BP EXPLORATION 71 / 2 - 30B/ME -01 Field: Endicott Sag /Ivishak ENG: D. Johnson Pad: MPI Producer RIG: Doyon 14 RKB: 48.8 ft DIR / LWD OH FORM DEPTH HOLE CASING MWD LOGS MD I TVD SIZE SPECS I Cement INFO 20.000 in NONE NONE Permafrost 91.1 -Ib /ft H -40 131' Welded a Surface Csq 13 -3/8" 68 # /ft NT80S, BTC i Int. Yield 5020 psi '> Collaspse 2260 psi A 6. Inter. Casing 9 -5/8" 69.3° 47 # /ft NT80S, BTC Int. Yield 6870 psi Collaspse 4750 psi Top of Section 5,850' 5,428' I 47° 1 12.25" Prod Tieback Cement Slurry None 7" Lead DIR 26 # /ft 15 bbls, 71 sx IFR /Cansandra Ugnu 6,690' 5,872' 62° E L -80 15.8 ppg GR /RES CM3 TCII 1.16 ft3 /sx Mudloggers i Int. Yield 7240 psi Class "G" Collaspse 5410 psi Prod Liner Cement Slurry 40% Excess 7" Tail CM3 10,848' 7,825' i 26 # /ft 216 bbls, 514 sx 62° i 13CR -80 L -80 11.8 ppg Hyd 521 2.36 ft3 /sx Top of Tail Cement 12,742' 8,824' Int. Yield 7240 psi LiteCrete Test Csg to Collaspse 5410 psi 4000 psi Tail 49 bbls, 237 sx Top Tuff Marker 13,159' 9,189' 20° i 15.8 ppg Top HRZ 13,449' 9,459' 1.16 ft3 /sx Base HRZ 13,669' 9,669' Class "G" 1 Dir /GR /RES TSGR 13,717 9,714' ::::,_' A IFR /Cansandra TSHU 13,802' 9,794' F. Veu /Den /Geo Tar TSAD 13,877' 9,864' Mudloggers TKVK 14,079' 10,054' Liner Point 14,164' 10,134' IA 20° a, 8.5 " Mrt 12/2/2008 2 -30B Well Plan Schematic.xls TREE: 4- 1/16" / 5000 psi /C on /Baker CAC END 2- 30B/ME -01 • WELLHEAD: 13 -5/8" /5000 p i / McEvoy R.T. ELEV = 48.8' MAX DEV = 63 Degrees 0 <— SSSV LANDING NIPPLE @ 1500' 13 -3/8 ", 68 # /ft, NT8OCYHE, BTC k Casing @ 2,709' 1 4 -1/2" X 1" Gaslift Mandrel @ 3,556' 9 -5/8 ", 47 # /ft, NT80S, BTC —> 7" Liner Hanger @ 5,700' MD — Z TOP OF 9 5/8" Window @ 5,850' —> E 4 -1/2" X 1" Gaslift Mandrel @ 6,711' C - 4 -1/2" X 1" Gaslift Mandrel @ 10,400' 4 -1/2 ", 12.6 # /ft, 13CR -80, VAMTOP Tubing —>' 4 -1/2" X 1" Gaslift Mandrel @ 12,600' [_ j ' 7 ", 26 # /ft, L -80, Hydril 521@ 12,989' I, •IIIE 4 -1/2" X 1" Gaslift Mandrel @ 13,400' 1 1 < 4 -1/2" "X" NIPPLE (3.813" ID) @ 13,570' 7" X 4 -1/2" Premier Packer @ 13,590' — Z Z I I 4 -1/2" "X" NIPPLE (3.813" ID) @ 13,610' I I < — 4 -1/2" "XN" NIPPLE (3.725" ID) @ 13,630' 4 -1/2" WLEG @ 13,650' Perforations to be determined 7 ", 26 # /ft, 13CR -80, Hydril 521 A @14,164'MD DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT 11/24/08 DJ Proposed Completion WELL: 2- 30B/ME-01 PEWIT No: API No: BP Exploration (Alaska) COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM BP Amoco Co-ordinate (N /E) Reference: Well Centre: 2- 30A/EIO2, True North t • • h Fm Depth To Survey /Plan Vertical (TVD) Reference: 14.5GL +34.3 48.80 Tool Plan: 2 - 30B wp 11 (2 - 30A/EIO2/Plan 2 - 30B) lculation Method: Minimum Curvature Section (VS) Reference: Slot - 30 (0.00N,0.00E) 850.00 14164.27 Planned: 2 -30B wp 11 V52 MWD +IFR +MS Created By: Sperry Drilling Date: 11/20/2008 Error System: ISCWSA Measured Depth Reference: 14.5GL +34.3 48.80 Scan Method: Tray Cylinder North Calculation Method: Minimum Curvature Error Surface: Elliptical + Casing WELL DETAILS CASING DETAILS Name +N / -S +E / -W Northing Easting Latitude Longitude Slot No. TVD MD Name Size 2- 30A/E102 3199.74 2176.87 5982464.78 258960.64 70 °21'09.824N 147 °57'26.880W 30 1 9713.80 13717.32 7" 7.000 SECTION DETAILS 2 10133.80 14164.27 4 1 -2" 4.500 Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target HALLIBURTON 1 5850.00 46.82 313.15 5426.09 972.13 - 938.06 0.00 0.00 938.06 2 5870.00 48.44 315.55 5439.56 982.46 - 948.62 12.00 48.40 948.62 3 6336.67 61.99 331.28 5706.30 1290.49 - 1171.85 4.00 48.40 1171.85 4 12114.37 61.99 331.28 8419.32 5764.13 3622.98 0.00 0.00 3622.98 Sperry Drilling Services 5 13164.27 20.00 332:00 9194.11 6355.85 - 3944.50 4.00 179.63 3944.50 5000 6 14164.27 20.00 332.00 10133.80 6657.84 - 4105.07 0.00 0.00 4105.07 .Minke Tl rev 5 Start Dir 12° /100' : 585Y MD, 5426.09'TVD Start Dir 4° /100' : 5871' MD, 5439.56'TVD End Dir : 6336, 5 7' MD, 5706.3' TVD 600( • 6000 7000 - 8000 \ . 7000 9000 C - O - 10000 0 - O _ 7 CM3 f, 8000 w F _ Sta Dir 4° /100' : 12114.37' MD, 8419.32'TVD 120 '0' • FORMATION TOP DETAILS 4,S 2-30A/E102 (2- 30A /E11 No. TVDPath MDPath Formation 31' 2- 30/0 -09 (2- 30A /PBI' End Du' : 13164.27' fv D, 9194.11' !VD ' 1 7824.80 10848.28 CM3 , 2 -30/0- 09(2- 30A/E1021 2 9188.80 13158.62 Top Tuff Marker Top Tuff Marker 2 - 30/0 - 09 (2 30A /PB2' 3 9458.80 13445.95 Top HRZ 4 9668.80 13669.43 Base HRZ .Minke Sag Target 5 9713.80 13717.32 TSGR Top HRZ ' .Minks TO SAG ,� 6 9793.80 13802.45 TSHU Base HRZ -, i . .Minks Fa t 3 .Minke Fault 1 7 9863.80 13876.94 TSAD TSG .Minke Fau] 2 - i 8 10053.80 14079.14 TKVK TSM3 Tn 1 Depth • 141 e4 77' MTV 1017712' TVD TARGET DETAILS TKVII, 01' r_ .Minks 1 rev 5 Name TVD +N / -S +E / -W Northing Easting Shape Plan 2-3, t 4 I - 2" 2 -30B wp 1 .Minke Fault 1 9713.80 6114.36 - 4980.97 5988736.01 254179.12 Polygon .Minke Fault 2 9713.80 7005.28 - 4190.49 5989601.00 254997.83 Polygon 2 -30/1- 09(2 - 30/0 -09) 1 b .Minke Fault 3 9713.80 6285.84 - 4347.23 5988887.00 254818.02 Polygon ��"�I .Minke TO SAG 9713.80 6524.47 - 4034.13 5989115.43 255138.63 Point 3000 4000 5000 " 8000 .Minke Sag Target 9713.80 6664.40 - 4106.12 5989257.60 255071.18 Polygon .Minke T1 rev 5 10133.80 6657.84 - 4105.07 5989251.00 255072.03 Circle (Radius: 150) Vertical Section at 270.00° [1000ft in] COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM BP Amoco ordinate (N /E) Reference: Well Centre: 2- 30A/E102, True North Depth Fm Depth To Survey /Plan Tool Plan: 2 -30B wp 11 (2- 30A/E102/Plan 2 -30B) Vertical (TVD) Reference: 14.5GL +34.3 48.80 Calculation Method: Minimum Curvature Section (VS) Reference: Slot - 30 (0.00N,0.00E) 5850.00 14164.27 Planned: 2 -30B wp 11 V52 MWD +IFR +MS Created By: Sperry Drilling Date: 11/20/2008 Error System: ISCWSA leasured Depth Reference: 14.5GL +34.3 48.80 Scan Method: Tray Cylinder North Calculation Method: Minimum Curvature WELL DETAILS Error Surface: Elliptical + Casing Warning Method: Rules Based _ Name +N / -S +E / -W Northing Easting Latitude Longitude Slot 95 % conf. i A ''' Depth : 14164.27' MD, 10133.8' TVD H L! A A 1.w >�r U �r �19� i1�1���■ 2- 30A/E102 3199.74 2176.87 5982464.78 258960.64 70 °21'09.824N 147 °57'26.880W 30 IR ■ M MinTc Sag Targct - - e T1 rev 5 Sperry Grilling Services 2 -30B wp 11 �� . j c cent-. o SAG TARGET DETAILS _ Plan 2 - 30B - 01 - %'' Name TVD +N / -S +E / -W Northing Easting Shape End Dir : 13.64.27' MD, 9194.11' TVD .M nkc Fault 'c 9 � . Minke Fault 1 9713.80 6114.36 - 4980.97 5988736.01 254179.12 Polygon �.Minke Fault 9001 . Minke Fault 9713.80 7005.28 - 4190.49 5989601.00 254997.83 Polygon . Minke Fault 3 9713.80 6285.84 - 4347.23 5988887.00 254818.02 Polygon 5994 .Minke TO SAG 9713.80 6524.47 - 4034.13 5989115.43 255138.63 Point Start Dir 4°7110' : 12114.37' MD; 8419.32'TVD .Minke Sag Target 9713.80 6664.40 - 4106.12 5989257.60 255071.18 Polygon - - . . Minke T1 rev 5 10133.80 6657.84 - 4105.07 5989251.00 255072.03 Circle (Radius: 150) - 850 CASING DETAILS - W ' 2 30/0 - 09 (2 30/0 - 19) No. TVD MD Name Size -_.. .._. 1 9713.80 13717.32 7" 7.000 - 2 10133.80 14164.27 4 1 -2" 4.500 4995 1lq I - -- 800 MI - I [fll - i 100( . lu �11 _ ... �T 1 1 __. 9500 750 FE 3996 ;i; �� c - .. 2- 30/0 -09 (2- 30A /PB I) 9(100 s -- 2- 30/0 -09 (2- 30A /E10:) A /E102 (2- 30A/E102) 8500 700 2- 30./0- - 0A /PB2) I I ! ! .... j 2997 8000 1 I T 1 _ _.. 8000 _ 500 7500 6501 _ 7000 7000 1998 i 6500 6500 6001 1 MEM ■■■■ E nd Dir : 6336.67' MD. 5706.3' TVD . i♦H111 Start Dir 4°/100' : 5877 MD, 5439.56TVD NU E= j Start Dir 12 °7100'0' MD, 5426.099 - FORMATION TOP DETAILS No. TVDPath MDPath Formation 8!00 1 7824.80 10848.28 CM3 SECTION DETAILS 2 9188.80 13158.62 Top Tuff Marker Sec MD Inc An TVD +N / - S +E/ - W DLeg TFace VSec Target 3 9458.80 13445.95 Top HRZ 4 9668.80 13669.43 Base HRZ 1 5850.00 46.82 313.15 5426.09 972.13 - 938.06 0.00 0.00 938.06 5 9713.80 13717.32 TSGR ':: 1: 1 : 1 1 1 i:: 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 2 5870.00 48.44 315.55 5439.56 982.46 - 948.62 12.00 48.40 948.62 6 9793.80 13802.45 TSHU - 4995 - 3996 -2997 -19 3 6336.67 61.99 331.28 5706.30 1290.49 - 1171.85 4.00 48.40 1171.85 - - 7 9863.80 13876.94 TSAD 4 12114.37 61.99 331.28 8419.32 5764.13 - 3622.98 0.00 0.00 3622.98 8 10053.80 14079.14 TKVK 5 13164.27 20.00 332.00 9194.11 6355.85 - 3944.50 4.00 179.63 3944.50 West( - /East( +; 6 14164.27 20.00 332.00 10133.80 6657.84 -4105.07 0.00 0.00 4105.07 .Minke Tl rev 5 • • Sperry -Sun BP Planning Report Company: BP Amoco Date: 11/20/2008 Time: 10:52:54 Page: 1 Field: Endicott Co- ordinate(NE) Reference: Well: 2- 30A/E102, True North Site: End MPI Vertical (TVD) Reference: 14.5GL +34.3 48.8 Well: 2- 30A/E102 Section (VS) Reference: Well (0.00N,0.00E,270.00Azi) Wellpath: Plan 2 -30B Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 2 -30B wp 11 Date Composed: 6/21/2005 Option C Version: 52 Principal: Yes Tied -to: From: Definitive Path Field: Endicott North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 3 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: End MPI TR -12 -16 UNITED STATES : North Slope Site Position: Northing: 5979337.49 ft Latitude: 70 20 38.358 N From: Map Easting: 256681.13 ft Longitude: 147 58 30.505 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -1.86 deg Well: 2- 30A/E102 Slot Name: 30 2- 30A/E102 Well Position: +N / -S 3199.74 ft Northing: 5982464.78 ft Latitude: 70 21 9.824 N +E / -W 2176.87 ft Easting : 258960.64 ft Longitude: 147 57 26.880 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 13717.32 9713.80 7.000 8.500 7" 14164.27 10133.80 4.500 5.125 41 -2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 10848.28 7824.80 CM3 0.00 0.00 13158.62 9188.80 Top Tuff Marker 0.00 0.00 13445.95 9458.80 Top HRZ 0.00 0.00 13669.43 9668.80 Base HRZ 0.00 0.00 13717.32 9713.80 TSGR 0.00 0.00 13802.45 9793.80 TSHU 0.00 0.00 13876.94 9863.80 TSAD 0.00 0.00 14079.14 10053.80 TKVK 0.00 0.00 0.00 TLSB 0.00 0.00 Targets Map Map < - -- Latitude - - - -> < -- Longitude --> Name Description TVD +N / -S +E / -W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft .Minke Fault 1 9713.80 6114.36 - 4980.97 5988736.01 254179.12 70 22 9.942 N 147 59 52.582 W - Polygon 1 9713.80 6114.36 - 4980.97 5988736.01 254179.12 70 22 9.942 N 147 59 52.582 W - Polygon 2 9713.80 6182.35 - 4889.10 5988801.01 254273.12 70 22 10.611 N 147 59 49.897 W - Polygon 3 9713.80 6214.36 - 4796.18 5988830.01 254367.02 70 22 10.927 N 147 59 47.179 W - Polygon 4 9713.80 6329.55 - 4730.05 5988943.01 254436.82 70 22 12.060 N 147 59 45.247 W - Polygon 5 9713.80 6412.58 - 4668.29 5989024.01 254501.22 70 22 12.877 N 147 59 43.441 W - Polygon 6 9713.80 6503.91 - 4566.47 5989112.01 254605.92 70 22 13.776 N 147 59 40.465 W - Polygon 7 9713.80 6604.06 - 4470.34 5989209.01 254705.22 70 22 14.761 N 147 59 37.654 W - Polygon 8 9713.80 6657.11 - 4407.51 5989260.01 254769.72 70 22 15.283 N 147 59 35.817 W - Polygon 9 9713.80 6690.30 - 4371.06 5989292.01 254807.22 70 22 15.610 N 147 59 34.751 W - Polygon 10 9713.80 6812.88 - 4323.98 5989413.01 254858.22 70 22 16.816 N 147 59 33.376 W - Polygon 11 9713.80 6876.62 - 4240.08 5989474.01 254944.12 70 22 17.443 N 147 59 30.923 W - Polygon 12 9713.80 6910.55 - 4211.56 5989507.01 254973.72 70 22 17.777 N 147 59 30.089 W - Polygon 13 9713.80 7002.37 - 4187.70 5989598.01 255000.52 70 22 18.680 N 147 59 29.392 W - Polygon 14 9713.80 6910.55 - 4211.56 5989507.01 254973.72 70 22 17.777 N 147 59 30.089 W - Polygon 15 9713.80 6876.62 - 4240.08 5989474.01 254944.12 70 22 17.443 N 147 59 30.923 W - Polygon 16 9713.80 6812.88 - 4323.98 5989413.01 254858.22 70 22 16.816 N 147 59 33.376 W 1 . Sperry -Sun BP Planning Report Company: BP Amoco Date: 11/20/2008 Time: 10:52:54 Page: 2 Field: Endicott Co- ordinate(NE) Reference: Well: 2- 30A/E102, True North Site: End MPI Vertical (TVD) Reference: 14.5GL +34.3 48.8 Well: 2- 30A/E102 Section (VS) Reference: Well (0.00N,0.00E,270.00Azi) Wellpath: Plan 2 -30B Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map < -__ Latitude - --> < -- Longitude - --> Name Description TVD +N / -S +E / -W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft - Polygon 17 9713.80 6812.88 - 4323.98 5989413.01 254858.22 70 22 16.816 N 147 59 33.376 W - Polygon 18 9713.80 6690.30 - 4371.06 5989292.01 254807.22 70 22 15.610 N 147 59 34.751 W - Polygon 19 9713.80 6657.11 - 4407.51 5989260.01 254769.72 70 22 15.283 N 147 59 35.817 W - Polygon 20 9713.80 6604.06 - 4470.34 5989209.01 254705.22 70 22 14.761 N 147 59 37.654 W - Polygon 21 9713.80 6503.91 - 4566.47 5989112.01 254605.92 70 22 13.776 N 147 59 40.465 W - Polygon 22 9713.80 6412.58 - 4668.29 5989024.01 254501.22 70 22 12.877 N 147 59 43.441 W - Polygon 23 9713.80 6329.55 - 4730.05 5988943.01 254436.82 70 22 12.060 N 147 59 45.247 W - Polygon 24 9713.80 6214.36 - 4796.18 5988830.01 254367.02 70 22 10.927 N 147 59 47.179 W - Polygon 25 9713.80 6182.35 - 4889.10 5988801.01 254273.12 70 22 10.611 N 147 59 49.897 W - Polygon 26 9713.80 6114.36 - 4980.97 5988736.01 254179.12 70 22 9.942 N 147 59 52.582 W -Plan out by 1031.96 at 9713.80 6522.86 - 4033.30 5989113.79 255139.41 70 22 13.965 N 147 59 24.868 W .Minke Fault 2 9713.80 7005.28 - 4190.49 5989601.00 254997.83 70 22 18.709 N 147 59 29.474 W - Polygon 1 9713.80 7005.28 - 4190.49 5989601.00 254997.83 70 22 18.709 N 147 59 29.474 W - Polygon 2 9713.80 6990.45 - 4122.88 5989584.00 255064.93 70 22 18.563 N 147 59 27.496 W - Polygon 3 9713.80 6905.43 - 4028.79 5989496.00 255156.23 70 22 17.728 N 147 59 24.742 W - Polygon 4 9713.80 6860.39 - 3935.99 5989448.00 255247.53 70 22 17.285 N 147 59 22.026 W - Polygon 5 9713.80 6821.12 - 3819.26 5989405.00 255362.93 70 22 16.900 N 147 59 18.611 W - Polygon 6 9713.80 6804.36 - 3687.15 5989384.00 255494.43 70 22 16.735 N 147 59 14.746 W - Polygon 7 9713.80 6769.83 - 3578.58 5989346.00 255601.83 70 22 16.396 N 147 59 11.569 W - Polygon 8 9713.80 6742.78 - 3486.46 5989316.00 255693.03 70 22 16.131 N 147 59 8.874 W - Polygon 9 9713.80 6774.84 - 3422.95 5989346.00 255757.53 70 22 16.446 N 147 59 7.017 W - Polygon 10 9713.80 6779.07 - 3291.52 5989346.00 255889.03 70 22 16.489 N 147 59 3.172 W - Polygon 11 9713.80 6758.71 - 3178.10 5989322.00 256001.73 70 22 16.289 N 147 58 59.853 W - Polygon 12 9713.80 6826.74 - 3054.02 5989386.00 256127.93 70 22 16.958 N 147 58 56.224 W - Polygon 13 9713.80 6921.89 - 2957.73 5989478.00 256227.23 70 22 17.894 N 147 58 53.408 W - Polygon 14 9713.80 6826.74 - 3054.02 5989386.00 256127.93 70 22 16.958 N 147 58 56.224 W - Polygon 15 9713.80 6758.71 - 3178.10 5989322.00 256001.73 70 22 16.289 N 147 58 59.853 W - Polygon 16 9713.80 6779.07 - 3291.52 5989346.00 255889.03 70 22 16.489 N 147 59 3.172 W - Polygon 17 9713.80 6774.84 - 3422.95 5989346.00 255757.53 70 22 16.446 N 147 59 7.017 W - Polygon 18 9713.80 6742.78 - 3486.46 5989316.00 255693.03 70 22 16.131 N 147 59 8.874 W - Polygon 19 9713.80 6769.83 - 3578.58 5989346.00 255601.83 70 22 16.396 N 147 59 11.569 W - Polygon 20 9713.80 6804.36 - 3687.15 5989384.00 255494.43 70 22 16.735 N 147 59 14.746 W - Polygon 21 9713.80 6821.12 - 3819.26 5989405.00 255362.93 70 22 16.900 N 147 59 18.611 W - Polygon 22 9713.80 6860.39 - 3935.99 5989448.00 255247.53 70 22 17.285 N 147 59 22.026 W - Polygon 23 9713.80 6905.43 - 4028.79 5989496.00 255156.23 70 22 17.728 N 147 59 24.742 W - Polygon 24 9713.80 6990.45 - 4122.88 5989584.00 255064.93 70 22 18.563 N 147 59 27.496 W -Plan out by 507.38 at 9713.80 6522.86 - 4033.30 5989113.79 255139.41 70 22 13.965 N 147 59 24.868 W .Minke Fault 3 9713.80 6285.84 - 4347.23 5988887.00 254818.02 70 22 11.632 N 147 59 34.048 W - Polygon 1 9713.80 6285.84 - 4347.23 5988887.00 254818.02 70 22 11.632 N 147 59 34.048 W - Polygon 2 9713.80 6247.11 - 4276.15 5988846.00 254887.82 70 22 11.252 N 147 59 31.967 W - Polygon 3 9713.80 6277.25 - 4209.98 5988874.00 254954.92 70 22 11.549 N 147 59 30.032 W - Polygon 4 9713.80 6203.52 - 4076.04 5988796.00 255086.42 70 22 10.824 N 147 59 26.113 W - Polygon 5 9713.80 6221.15 - 4025.58 5988812.00 255137.42 70 22 10.998 N 147 59 24.637 W - Polygon 6 9713.80 6290.11 - 3966.06 5988879.00 255199.12 70 22 11.676 N 147 59 22.897 W - Polygon 7 9713.80 6274.93 - 3909.14 5988862.00 255255.52 70 22 11.527 N 147 59 21.232 W - Polygon 8 9713.80 6330.10 - 3811.56 5988914.00 255354.82 70 22 12.070 N 147 59 18.378 W - Polygon 9 9713.80 6272.46 - 3737.17 5988854.00 255427.32 70 22 11.504 N 147 59 16.201 W - Polygon 10 9713.80 6289.30 - 3649.06 5988868.00 255515.92 70 22 11.670 N 147 59 13.624 W - Polygon 11 9713.80 6256.16 - 3497.61 5988830.00 255666.22 70 22 11.345 N 147 59 9.193 W - Polygon 12 9713.80 6278.74 - 3417.79 5988850.00 255746.72 70 22 11.567 N 147 59 6.859 W - Polygon 13 9713.80 6256.16 - 3497.61 5988830.00 255666.22 70 22 11.345 N 147 59 9.193 W - Polygon 14 9713.80 6289.30 - 3649.06 5988868.00 255515.92 70 22 11.670 N 147 59 13.624 W - Polygon 15 9713.80 6272.46 - 3737.17 5988854.00 255427.32 70 22 11.504 N 147 59 16.201 W - Polygon 16 9713.80 6330.10 - 3811.56 5988914.00 255354.82 70 22 12.070 N 147 59 18.378 W - Polygon 17 9713.80 6274.93 - 3909.14 5988862.00 255255.52 70 22 11.527 N 147 59 21.232 W - Polygon 18 9713.80 6290.11 - 3966.06 5988879.00 255199.12 70 22 11.676 N 147 59 22.897 W - Polygon 19 9713.80 6221.15 - 4025.58 5988812.00 255137.42 70 22 10.998 N 147 59 24.637 W - Polygon 20 9713.80 6203.52 - 4076.04 5988796.00 255086.42 70 22 10.824 N 147 59 26.113 W - Polygon 21 9713.80 6277.25 - 4209.98 5988874.00 254954.92 70 22 11.549 N 147 59 30.032 W - Polygon 22 9713.80 6247.11 - 4276.15 5988846.00 254887.82 70 22 11.252 N 147 59 31.967 W - Polygon 23 9713.80 6285.84 - 4347.23 5988887.00 254818.02 70 22 11.632 N 147 59 34.048 W -Plan out by 393.36 at 9713.80 6522.86 - 4033.30 5989113.79 255139.41 70 22 13.965 N 147 59 24.868 W .Minke TO SAG 9713.80 6524.47 - 4034.13 5989115.43 255138.63 70 22 13.981 N 147 59 24.892 W • Sperry -Sun BP Planning Report Company: BP Amoco Date: 11/20/2008 Time: 10:52:54 Page: 3 Field: Endicott Co- ordinate(NE) Reference: Well: 2- 30A/E102, True North Site: End MPI Vertical (TVD) Reference: 14.5GL +34.3 48.8 Well: 2- 30A/E102 Section (VS) Reference: Well (0.00N,0.00E,270.00Azi) Wellpath: Plan 2 -30B Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map < - -- Latitude - --> < -- Longitude - - -> Name Description TVD +N /-S +E / -W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft - Plan out by 1.81 at 9713.80 6522.86 - 4033.30 5989113.79 255139.41 70 22 13.965 N 147 59 24.868 W .Minke Sag Target 9713.80 6664.40 - 4106.12 5989257.60 255071.18 70 22 15.357 N 147 59 27.001 W - Polygon 1 9713.80 6664.40 - 4106.12 5989257.60 255071.18 70 22 15.357 N 147 59 27.001 W - Polygon 2 9713.80 6518.86 - 4353.62 5989120.10 254819.13 70 22 13.924 N 147 59 34.238 W - Polygon 3 9713.80 6397.89 - 4226.29 5988995.10 254942.51 70 22 12.735 N 147 59 30.511 W - Polygon 4 9713.80 6363.26 - 4058.78 5988955.10 255108.81 70 22 12.395 N 147 59 25.611 W - Polygon 5 9713.80 6461.63 - 3815.86 5989045.60 255354.76 70 22 13.364 N 147 59 18.506 W - Polygon 6 9713.80 6554.75 - 3705.01 5989135.10 255468.54 70 22 14.280 N 147 59 15.265 W -Plan out by 159.18 at 9713.80 6522.86 - 4033.30 5989113.79 255139.41 70 22 13.965 N 147 59 24.868 W .Minke T1 rev 5 10133.80 6657.84 - 4105.07 5989251.00 255072.03 70 22 15.292 N 147 59 26.970 W - Circle (Radius: 150) -Plan hit target Plan Section Information MD lncl Azim TVD +N / - +E / -W DLS Build Tum TFO Target ft deg deg ft ft ft deg /100ft deg /100ft deg /100ft deg 5850.00 46.82 313.15 5426.09 972.13 - 938.06 0.00 0.00 0.00 0.00 5870.00 48.44 315.55 5439.56 982.46 - 948.62 12.00 8.09 11.99 48.40 6336.67 61.99 331.28 5706.30 1290.49 - 1171.85 4.00 2.91 3.37 48.40 12114.37 61.99 331.28 8419.32 5764.13 - 3622.98 0.00 0.00 0.00 0.00 13164.27 20.00 332.00 9194.11 6355.85 - 3944.50 4.00 -4.00 0.07 179.63 14164.27 20.00 332.00 10133.80 6657.84 - 4105.07 0.00 0.00 0.00 0.00 .Minke T1 rev 5 Survey MD lncl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Co ent ft deg deg ft ft ft ft ft deg /100ft ft ft 5850.00 46.82 313.15 5426.09 5377.29 938.06 972.13 - 938.06 0.00 5983466.55 258054.37 Start Dir 1 ° 5870.00 48.44 315.55 5439.56 5390.76 948.62 982.46 - 948.62 12.00 5983477.22 258044.15 Start Dir 4° 1e 5900.00 49.24 316.74 5459.31 5410.51 964.27 998.75 - 964.27 4.00 5983494.00 258029.03 MWD +IFR S 6000.00 52.00 320.49 5522.77 5473.97 1015.32 1056.75 - 1015.32 4.00 5983553.61 257979.88 MWD +IFR S 6100.00 54.87 323.96 5582.35 5533.55 1064.46 1120.23 - 1064.46 4.00 5983618.64 257932.80 MWD +IFR S 6200.00 57.83 327.19 5637.77 5588.97 1111.47 1188.89 - 1111.47 4.00 5983688.77 257888.03 MWD +IFR S 6300.00 60.86 330.22 5688.76 5639.96 1156.11 1262.40 - 1156.11 4.00 5983763.67 257845.78 MWD +IFR S 6336.67 61.99 331.28 5706.30 5657.50 1171.85 1290.49 - 1171.85 4.00 5983792.26 257830.96 End Dir : r6 6400.00 61.99 331.28 5736.04 5687.24 1198.72 1339.53 - 1198.72 0.00 5983842.14 257805.68 MWD +IFR S 6500.00 61.99 331.28 5783.00 5734.20 1241.14 1416.96 - 1241.14 0.00 5983920.89 257765.77 MWD +IFR S 6600.00 61.99 331.28 5829.95 5781.15 1283.56 1494.39 - 1283.56 0.00 5983999.64 257725.86 MWD +IFR S 6700.00 61.99 331.28 5876.91 5828.11 1325.99 1571.82 - 1325.99 0.00 5984078.39 257685.95 MWD +IFR S 6800.00 61.99 331.28 5923.87 5875.07 1368.41 1649.25 - 1368.41 0.00 5984157.14 257646.04 MWD +IFR S 6900.00 61.99 331.28 5970.82 5922.02 1410.84 1726.68 - 1410.84 0.00 5984235.89 257606.13 MWD +IFR S 7000.00 61.99 331.28 6017.78 5968.98 1453.26 1804.11 - 1453.26 0.00 5984314.64 257566.22 MWD +IFR S 7100.00 61.99 331.28 6064.73 6015.93 1495.68 1881.54 - 1495.68 0.00 5984393.39 257526.31 MWD +IFR S 7200.00 61.99 331.28 6111.69 6062.89 1538.11 1958.97 - 1538.11 0.00 5984472.15 257486.40 MWD +IFR S 7300.00 61.99 331.28 6158.65 6109.85 1580.53 2036.40 - 1580.53 0.00 5984550.90 257446.49 MWD +IFR S 7400.00 61.99 331.28 6205.60 6156.80 1622.96 2113.82 - 1622.96 0.00 5984629.65 257406.58 MWD +IFR S 7500.00 61.99 331.28 6252.56 6203.76 1665.38 2191.25 - 1665.38 0.00 5984708.40 257366.67 MWD +IFR S 7600.00 61.99 331.28 6299.52 6250.72 1707.80 2268.68 - 1707.80 0.00 5984787.15 257326.77 MWD +IFR S 7700.00 61.99 331.28 6346.47 6297.67 1750.23 2346.11 - 1750.23 0.00 5984865.90 257286.86 MWD +IFR S 7800.00 61.99 331.28 6393.43 6344.63 1792.65 2423.54 - 1792.65 0.00 5984944.65 257246.95 MWD +IFR S 7900.00 61.99 331.28 6440.39 6391.59 1835.07 2500.97 - 1835.07 0.00 5985023.40 257207.04 MWD +IFR S 8000.00 61.99 331.28 6487.34 6438.54 1877.50 2578.40 - 1877.50 0.00 5985102.16 257167.13 MWD +IFR S 8100.00 61.99 331.28 6534.30 6485.50 1919.92 2655.83 - 1919.92 0.00 5985180.91 257127.22 MWD +IFR S 8200.00 61.99 331.28 6581.26 6532.46 1962.35 2733.26 - 1962.35 0.00 5985259.66 257087.31 MWD +IFR S 8300.00 61.99 331.28 6628.21 6579.41 2004.77 2810.69 - 2004.77 0.00 5985338.41 257047.40 MWD +IFR S 8400.00 61.99 331.28 6675.17 6626.37 2047.19 2888.12 - 2047.19 0.00 5985417.16 257007.49 MWD +IFR S 8500.00 61.99 331.28 6722.13 6673.33 2089.62 2965.55 - 2089.62 0.00 5985495.91 256967.58 MWD +IFR S . • Sperry -Sun BP Planning Report Company: BP Amoco Date: 11/20/2008 Time: 10:52:54 Page: 4 Field: Endicott Co- ordinate(NE) Reference: Well: 2- 30A/EIO2, True North Site: End MPI Vertical (TVD) Reference: 14.5GL +34.3 48.8 Well: 2- 30A/E102 Section (VS) Reference: Well (0.00N,0.00E,270.00Azi) Wellpath: Plan 2 -30B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Co nent ft deg deg ft ft ft ft ft deg /100ft ft ft 8600.00 61.99 331.28 6769.08 6720.28 2132.04 3042.97 - 2132.04 0.00 5985574.66 256927.67 MWD +IFR MS 8700.00 61.99 331.28 6816.04 6767.24 2174.47 3120.40 - 2174.47 0.00 5985653.41 256887.76 MWD +IFR MS 8800.00 61.99 331.28 6863.00 6814.20 2216.89 3197.83 - 2216.89 0.00 5985732.17 256847.85 MWD +IFR MS 8900.00 61.99 331.28 6909.95 6861.15 2259.31 3275.26 - 2259.31 0.00 5985810.92 256807.94 MWD +IFR MS 9000.00 61.99 331.28 6956.91 6908.11 2301.74 3352.69 - 2301.74 0.00 5985889.67 256768.03 MWD +IFR MS 9100.00 61.99 331.28 7003.87 6955.07 2344.16 3430.12 - 2344.16 0.00 5985968.42 256728.12 MWD +IFR MS 9200.00 61.99 331.28 7050.82 7002.02 2386.59 3507.55 - 2386.59 0.00 5986047.17 256688.21 MWD +IFR MS 9300.00 61.99 331.28 7097.78 7048.98 2429.01 3584.98 - 2429.01 0.00 5986125.92 256648.30 MWD +IFR MS 9400.00 61.99 331.28 7144.74 7095.94 2471.43 3662.41 - 2471.43 0.00 5986204.67 256608.39 MWD +IFR MS 9500.00 61.99 331.28 7191.69 7142.89 2513.86 3739.84 - 2513.86 0.00 5986283.43 256568.48 MWD +IFR MS 9600.00 61.99 331.28 7238.65 7189.85 2556.28 3817.27 - 2556.28 0.00 5986362.18 256528.57 MWD +IFR MS 9700.00 61.99 331.28 7285.61 7236.81 2598.71 3894.70 - 2598.71 0.00 5986440.93 256488.66 MWD +IFR MS 9800.00 61.99 331.28 7332.56 7283.76 2641.13 3972.13 - 2641.13 0.00 5986519.68 256448.75 MWD +IFR MS 9900.00 61.99 331.28 7379.52 7330.72 2683.55 4049.55 - 2683.55 0.00 5986598.43 256408.84 MWD +IFR MS 10000.00 61.99 331.28 7426.48 7377.68 2725.98 4126.98 - 2725.98 0.00 5986677.18 256368.93 MWD +IFR MS 10100.00 61.99 331.28 7473.43 7424.63 2768.40 4204.41 - 2768.40 0.00 5986755.93 256329.03 MWD +IFR MS 10200.00 61.99 331.28 7520.39 7471.59 2810.83 4281.84 - 2810.83 0.00 5986834.68 256289.12 MWD +IFR MS 10300.00 61.99 331.28 7567.35 7518.55 2853.25 4359.27 - 2853.25 0.00 5986913.44 256249.21 MWD +IFR MS 10400.00 61.99 331.28 7614.30 7565.50 2895.67 4436.70 - 2895.67 0.00 5986992.19 256209.30 MWD +IFR MS 10500.00 61.99 331.28 7661.26 7612.46 2938.10 4514.13 - 2938.10 0.00 5987070.94 256169.39 MWD +IFR MS 10600.00 61.99 331.28 7708.22 7659.42 2980.52 4591.56 - 2980.52 0.00 5987149.69 256129.48 MWD +IFR MS 10700.00 61.99 331.28 7755.17 7706.37 3022.95 4668.99 - 3022.95 0.00 5987228.44 256089.57 MWD +IFR MS 10800.00 61.99 331.28 7802.13 7753.33 3065.37 4746.42 - 3065.37 0.00 5987307.19 256049.66 MWD +IFR MS 10848.28 61.99 331.28 7824.80 7776.00 3085.85 4783.80 - 3085.85 0.00 5987345.21 256030.39 CM3 10900.00 61.99 331.28 7849.09 7800.29 3107.79 4823.85 - 3107.79 0.00 5987385.94 256009.75 MWD +IFR MS 11000.00 61.99 331.28 7896.04 7847.24 3150.22 4901.28 - 3150.22 0.00 5987464.69 255969.84 MWD +IFR MS 11100.00 61.99 331.28 7943.00 7894.20 3192.64 4978.70 - 3192.64 0.00 5987543.45 255929.93 MWD +IFR MS 11200.00 61.99 331.28 7989.96 7941.16 3235.07 5056.13 - 3235.07 0.00 5987622.20 255890.02 MWD +IFR MS 11300.00 61.99 331.28 8036.91 7988.11 3277.49 5133.56 - 3277.49 0.00 5987700.95 255850.11 MWD +IFR MS 11400.00 61.99 331.28 8083.87 8035.07 3319.91 5210.99 - 3319.91 0.00 5987779.70 255810.20 MWD +IFR MS 11500.00 61.99 331.28 8130.83 8082.03 3362.34 5288.42 - 3362.34 0.00 5987858.45 255770.29 MWD +IFR MS 11600.00 61.99 331.28 8177.78 8128.98 3404.76 5365.85 - 3404.76 0.00 5987937.20 255730.38 MWD +IFR MS 11700.00 61.99 331.28 8224.74 8175.94 3447.18 5443.28 - 3447.19 0.00 5988015.95 255690.47 MWD +IFR MS 11800.00 61.99 331.28 8271.70 8222.90 3489.61 5520.71 - 3489.61 0.00 5988094.71 255650.56 MWD +IFR MS 11900.00 61.99 331.28 8318.65 8269.85 3532.03 5598.14 - 3532.03 0.00 5988173.46 255610.65 MWD +IFR MS 12000.00 61.99 331.28 8365.61 8316.81 3574.46 5675.57 - 3574.46 0.00 5988252.21 255570.74 MWD +IFR MS 12100.00 61.99 331.28 8412.57 8363.77 3616.88 5753.00 - 3616.88 0.00 5988330.96 255530.83 MWD +IFR NS 12114.37 61.99 331.28 8419.32 8370.52 3622.98 5764.13 - 3622.98 0.00 5988342.28 255525.10 Start Dir 4° 1) 12200.00 58.57 331.31 8461.76 8412.96 3658.69 5829.34 - 3658.69 4.00 5988408.61 255491.50 MWD +IFR MS 12300.00 54.57 331.34 8516.84 8468.04 3698.73 5902.54 - 3698.73 4.00 5988483.06 255453.84 MWD +IFR MS 12400.00 50.57 331.38 8577.61 8528.81 3736.79 5972.22 - 3736.79 4.00 5988553.92 255418.04 MWD +IFR MS 12500.00 46.57 331.42 8643.77 8594.97 3772.68 6038.03 - 3772.68 4.00 5988620.85 255384.29 MWD +IFR MS 12600.00 42.57 331.46 8714.99 8666.19 3806.22 6099.66 - 3806.22 4.00 5988683.52 255352.75 MWD +IFR MS 12700.00 38.57 331.52 8790.94 8742.14 3837.26 6156.79 - 3837.26 4.00 5988741.62 255323.57 MWD +IFR MS 12800.00 34.57 331.58 8871.24 8822.44 3865.64 6209.17 - 3865.64 4.00 5988794.88 255296.88 MWD +IFR MS 12900.00 30.57 331.66 8955.49 8906.69 3891.23 6256.52 - 3891.23 4.00 5988843.03 255272.84 MWD +IFR MS 13000.00 26.57 331.76 9043.30 8994.50 3913.89 6298.62 - 3913.89 4.00 5988885.83 255251.54 MWD +IFR S 13100.00 22.57 331.89 9134.23 9085.43 3933.52 6335.26 - 3933.52 4.00 5988923.09 255233.10 MWD +IFR MS 13158.62 20.23 331.99 9188.80 9140.00 3943.59 6354.13 - 3943.59 4.00 5988942.27 255223.65 Top Tuff M : mer 13164.27 20.00 332.00 9194.11 9145.31 3944.50 6355.85 - 3944.50 4.00 5988944.02 255222.79 End Dir : 1 16 13200.00 20.00 332.00 9227.68 9178.88 3950.23 6366.64 - 3950.24 0.00 5988954.99 255217.40 MWD +IFR MS 13300.00 20.00 332.00 9321.65 9272.85 3966.29 6396.84 - 3966.29 0.00 5988985.68 255202.33 MWD +IFR MS Sperry -Sun BP Planning Report Company: BP Amoco Date: 11/20/2008 Time: 10:52:54 Page: 5 Field: Endicott Co- ordinate(NE) Reference: Well: 2 - 30A/E102, True North Site: End MPI Vertical (TVD) Reference: 14.5GL +34.3 48.8 Well: 2- 30A/E102 Section (VS) Reference: Well (0.00N,0.00E,270.00Azi) Wellpath: Plan 2 -30B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Co - rent ft deg deg ft ft ft ft ft deg/100ft ft ft 13400.00 20.00 332.00 9415.62 9366.82 3982.35 6427.04 - 3982.35 0.00 5989016.38 255187.25 MWD + IFR MS 13445.95 20.00 332.00 9458.80 9410.00 3989.73 6440.91 - 3989.73 0.00 5989030.49 255180.32 Top HRZ 13500.00 20.00 332.00 9509.59 9460.79 3998.41 6457.23 - 3998.41 0.00 5989047.08 255172.17 MWD +IFR MS 13600.00 20.00 332.00 9603.56 9554.76 4014.46 6487.43 -4014.46 0.00 5989077.78 255157.10 MWD +IFR MS 13669.43 20.00 332.00 9668.80 9620.00 4025.61 6508.40 - 4025.61 0.00 5989099.09 255146.63 Base HRZ 13700.00 20.00 332.00 9697.53 9648.73 4030.52 6517.63 - 4030.52 0.00 5989108.48 255142.02 MWD +IFR MS 13717.32 20.00 332.00 9713.80 9665.00 4033.30 6522.86 - 4033.30 0.00 5989113.79 255139.41 .TSGR 13800.00 20.00 332.00 9791.50 9742.70 4046.58 6547.83 - 4046.58 0.00 5989139.18 255126.94 MWD +IFR MS 13802.45 20.00 332.00 9793.80 9745.00 4046.97 6548.57 - 4046.97 0.00 5989139.93 255126.58 TSHU 13876.94 20.00 332.00 9863.80 9815.00 4058.93 6571.07 - 4058.93 0.00 5989162.80 255115.34 TSAD 13900.00 20.00 332.00 9885.47 9836.67 4062.63 6578.03 - 4062.63 0.00 5989169.88 255111.87 MWD +IFR MS 14000.00 20.00 332.00 9979.44 9930.64 4078.69 6608.23 - 4078.69 0.00 5989200.57 255096.79 MWD +IFR MS 14079.14 20.00 332.00 10053.80 10005.00 4091.40 6632.13 - 4091.40 0.00 5989224.87 255084.86 TKVK 14100.00 20.00 332.00 10073.40 10024.60 4094.75 6638.43 - 4094.75 0.00 5989231.27 255081.72 MWD +IFR MS 14164.27 20.00 332.00 10133.80 10085.00 4105.07 6657.83 - 4105.07 0.00 5989251.00 255072.03 .Minke T1 -v 5 14164.26 20.00 332.00 10133.79 10084.99 4105.06 6657.83 - 4105.07 0.00 5989251.00 255072.03 Total Dept : 1 14164.27 20.00 332.00 10133.80 10085.00 4105.07 6657.84 - 4105.07 0.00 5989251.00 255072.03 MWD +IFR MS WELL DETAILS ANTI - COLLISION SETTINGS COMPANY DETAILS SURVEY PROGRAM Name +N /-S +E/ -W Northing Eastmg Latitude Longitude Slot BP Amoco Depth Fm Depth I Survey /Plan Tool Interpolation MethodNID Interval: 25.00 2 30A/E102 3199.74 217687 5982464.78 258960.64 70 147 °57 30 Depth Range From: 5850.00 To: 14164.27 Calculation Method: Minimum Curvature 5850.00 14164.27 Planned: 2 - 300 wp 11 V51 MWD +IFR +MS Maximum Range: 1613.00 Reference: Plan: 2 - 30B wp 11 Error Syaum: rscWSA Scan Method: limy Cylinder North Error Surface: Elliptical +Casing E Warning Method: Rules Based 0 WF.LLPATH DETAILS - 160 V ' From Colour MD Plan 2-3013 - 150 0 500 To PSlie onWarmth: D: 5850.00 102 - • 2 50 500 500 750 Re0 Datum: 14.50,34.3 48.8010 33►. - 0 750 1000 / _ 1000 v.Secann Origin Origin sm ting 1250 Angle NAS +E/ -W From g TVD 1250 1500 270.00° 0.00 0.00 34.30 - 125 % 1500 1750 1750 2000 ✓/� �-��- 2000 2250 2250 2500 LEGEND - 2- 20/415 (2- 20/L -15), Major Risk - 100 .! • : . 2500 2750 - 2- 22/414(2- 22/L -14) Major Risk 2750 3000 - 2- 24/M -12 (2- 24/M -12). Major Risk 2- 2699 -14 (2- 2699 -14). Major Risk 3000 3250 - 2- 30/0-09 (2- 30/0-09), NOERRORS - 2- 30/0-09 (2- 30A/EIO2(. NOERRORS 3250 3500 - 2 -30/0- 09(2- 30A/PB1). NOERRORS 3 3500 3750 9.9.9 2- 30/0.09 (2- 30A/PB21, NOERRORS `75 3 750 4000 - 2-30A/E102 (2-30A/002), . M a jor NOERRORS Risk -- 2-48/0-13 (2 -48/013PI1). Major Risk 4000 4250 - Plan 2-308 4250 4500 - 2-30B wp 11 .500 4750 -50 a 50 5000 100 5250 )0 5500 X25 1 - 0 270 90 � 1 - 25 1', -50 ii -75 240 120 - 100 i e Pre Plans Removed. See AC Scan for Plans Parents Profile @ No Errors - 125 j - .1 yY 4,,, _� %� . SECTION DETAILS - Sec MD Inc Av IVD -N' -S -E -W DLeg TFace VSO* "Iargot 211 Ib 50 1 5850.01 46.82 313.15 5426.09 972.13 - 938.06 0.00 0.00 93806 2 5870.00 48.44 315.55 5479.56 982.46 - 948.62 (2.(0 48.40 948.62 3 6336.67 61.99 331.28 5706.30 1290.49 - 1171.85 4.00 48.40 117185 - 150 ' 4 12114.37 20.99 331.28 9114.11 6355.15 - 3944.50 0.00 0.00 3622.98 . ".' ; 5 13164.27 20.00 332.00 9194.11 6657.84 -3944.50 0.00 179.63 3944.50 -160 !'!'• - 6 14164.27 20.00 332.(99) ,00 10137.80 6657.84 -0105.07 0.00 0(10 410507 .MmI:e TI rev • r ., A r-. r--4 T Travelling Cylinder Azirn II 1 It 1) [ g] vs C ' 111 N Sjon ' ftJin] jj . . • • Sperry -Sun Anticollision Report Company: BP Amoco Date: 11/20/2008 Time: 10:54:29 Page: 1 Field: Endicott Reference Site: End MPI Co- ordinate(NE) Reference: Well: 2- 30A/E102, True North Reference Well: 2- 30A/E102 Vertical (TVD) Reference: 14.5GL +34.3 48.8 Reference Wellpath: Plan 2 -30B Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100 /1000 of reference - There are '111 dllwatils in this t1 Iillcipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 5850.00 to 14164.27 ft Scan Method: Tray Cylinder North Maximum Radius: 1613.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 6/21/2005 Validated: No Version: 1 Planned From To Survey Toolcode Tool Name ft ft 83.10 5850.00 1 : Gyrodata cont.drillpipe m/ (93.47 - 15643.47 D- CT -DMS Gyrodata cont.drillpipe m/s 5850.00 14164.27 Planned: 2 -30B wp 11 V52 MWD +IFR +MS MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 13717.32 9713.80 7.000 8.500 7" 14164.27 10133.80 4.500 5.125 4 1 -2" Summary <- _- _- _ - -_ -__ Offset Wellpath ------------- - - ---> Reference Offset Ctr -Ctr No -Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft 2- 30A/E102,PIan 2 -30B, 14100.00 14100.00 0.00 196.65 - 196.65 FAIL: Major Risk End MPI 2- 20/L -15 2- 20/L -15 V1 5867.09 6050.00 682.75 87.90 594.85 Pass: Major Risk End MPI 2- 22/L -14 2- 22/L -14 V1 5883.37 6050.00 619.32 92.06 527.26 Pass: Major Risk End MPI 2- 24/M -12 2- 24/M -12 V1 7469.99 7100.00 456.99 132.17 324.82 Pass: Major Risk End MPI 2- 26/N -14 2- 26/N -14 V1 5855.29 6375.00 1045.26 78.83 966.43 Pass: Major Risk End MPI 2- 30/0 -09 2- 30/0 -09 V5 5867.74 5875.00 0.52 0.65 -0.13 FAIL: NOERRORS End MPI 2- 30/0 -09 2- 30A/E102 V2 5868.41 5875.00 0.51 0.65 -0.13 FAIL: NOERRORS End MPI 2- 30/0 -09 2- 30A/PB1 V2 5868.41 5875.00 0.51 0.65 -0.13 FAIL: NOERRORS End MPI 2- 30/0 -09 2- 30A/PB2 V2 5868.41 5875.00 0.51 0.65 -0.13 FAIL: NOERRORS End MPI 2- 30A/E102 2- 30A/E102 V5 5867.79 5875.00 0.31 0.82 -0.51 FAIL: NOERRORS End MPI 2- 48/0 -13 2- 48/0 -13 V1 5858.96 5775.00 503.56 105.89 397.68 Pass: Major Risk End MPI 2- 48/0 -13 2- 48/O13PH V3 5858.96 5775.00 503.56 105.89 397.68 Pass: Major Risk Site: I Well: Rule Assigned: Major Risk Wellpath: 2- 30A/E102,PIan 2- 30B,2 -30B wp 11 Inter -Site Error: 0.00 ft Reference Offset Semi -Major Axis Ctr -Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO +AZI TFO -HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 5850.00 5426.09 5850.00 5426.09 11.07 0.00 313.15 0.00 8.500 0.00 66.72 -66.72 FAIL 5875.00 5442.88 5875.00 5442.88 11.13 0.11 315.75 0.00 8.500 0.00 67.04 -67.04 FAIL 5900.00 5459.31 5900.00 5459.31 11.14 0.24 316.74 0.00 8.500 0.00 67.15 -67.15 FAIL 5925.00 5475.52 5925.00 5475.52 11.14 0.47 317.70 0.00 8.500 0.00 67.30 -67.30 FAIL 5950.00 5491.04 5950.00 5491.50 11.14 0.62 185.73 225.24 8.500 0.87 64.17 -63.30 FAIL 5975.00 5507.25 5975.00 5507.25 11.15 0.73 319.58 0.00 8.500 0.00 67.59 -67.59 FAIL 6000.00 5522.77 6000.00 5522.77 11.15 0.84 320.49 0.00 8.500 0.00 67.72 -67.72 FAIL 6025.00 5538.04 6025.00 5538.04 11.15 1.08 321.38 0.00 8.500 0.00 67.60 -67.60 FAIL 6050.00 5553.06 6050.00 5553.06 11.16 1.24 322.25 0.00 8.500 0.00 67.74 -67.74 FAIL 6075.00 5567.83 6075.00 5567.83 11.17 1.36 323.11 0.00 8.500 0.00 68.02 -68.02 FAIL 6100.00 5582.35 6100.00 5582.35 11.17 1.45 323.96 0.00 8.500 0.00 68.35 -68.35 FAIL 6125.00 5596.61 6125.00 5596.61 11.18 1.57 324.79 0.00 8.500 0.00 68.66 -68.66 FAIL 6150.00 5610.60 6150.00 5610.60 11.19 1.71 325.60 0.00 8.500 0.00 68.85 -68.85 FAIL 6175.00 5624.32 6175.00 5624.32 11.20 1.88 326.40 0.00 8.500 0.00 68.97 -68.97 FAIL 6200.00 5637.77 6200.00 5637.77 11.21 2.07 327.19 0.00 8.500 0.00 69.03 -69.03 FAIL 6225.00 5650.95 6225.00 5650.95 11.22 2.22 327.97 0.00 8.500 0.00 69.24 -69.24 FAIL 6250.00 5663.84 6250.00 5663.84 11.23 2.38 328.73 0.00 8.500 0.00 69.44 -69.44 FAIL 6275.00 5676.45 6275.00 5676.45 11.25 2.54 329.48 0.00 8.500 0.00 69.61 -69.61 FAIL 6300.00 5688.76 6300.00 5688.76 11.26 2.69 330.22 0.00 8.500 0.00 69.78 -69.78 FAIL 6325.00 5700.79 6325.00 5700.79 11.28 2.85 330.95 0.00 8.500 0.00 69.98 -69.98 FAIL Alaska Department of Natural Resources Land Administration System Page 1 of,ef 1110 IIP Records/Status Plats Recorders Search State Cabins Natural Resources Alaska DNR Case Summary File Type: PT: File Number: I 34633 a Printable Case File Summary See Township, Range, Section and Acreage? 1 ** 41 -4earch tfYesL No LAS Menu Case Abstract Case Detail 1 Land Abstract File: ADL 34633 4. Search for Status Plat Updates As of 12/04/2008 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 03/13/1967 Total Acres: 2560.000 Date Initiated: 12/23/1966 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/31/2002 Case Subtype: NS NORTH SLOPE Last Transaction: CDESTAND STATUS CODE STANDARDIZED Meridian: U Township: 012N Range: 016E Section: 25 Section Acres: 640 Search Plat* Meridian: U Township: 012N Range: 016E Section: 26 Section Acres: 640 Meridian: U Township: 01 2N Range: 016E Section: 35 Section Acres: 640 Meridian: U Township: 012N Range: 016E Section: 36 Section Acres: 640 Legal Description 12-23-1966 *** SALE NOTICE LEGAL DESCRIPTION ** * C18-12 T 12N., R. 16E., UM SECTION 25: ALL 640 ACRES SECTION 26: ALL 640 ACRES SECTION 35: ALL 640 ACRES SECTION 36: ALL 640 ACRES http://dnr.alaska.gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber=3463... 12/4/2008 • TRANSMITTAL LETTER CHECKLIST WELL NAME 4WD a 3 7 / A o/ , 4'' PTD# 0 ?08 /41" ✓ Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: Z" /C077 POOL: ZA44S; . /4 D Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool ENDICOTT, ENDICOTT OIL - 220100-17 P Well Name: DUCK IS UNIT MPI 2-30B/ME-01 Program DEV Well bore seg il PTD#: 2081870 Company BP EXPLORATION (AL INC —___....- Initial Class/ Type DEV / PEND Geo Area 890 10450 On/Off Shore Off Annular Disposal [1 Administration 1 _Permit fee attached NA 2 Leasenurnber appropriate Yes 3 Unique well name and number Yes 4 Well_located in a definedpool No Well will be drilled to a new fault block. Targets Sag / lvishak. 5 _Well located proper distance_ from drilling unit boundary Yes 6 Welllocated proper distance from other wells Yes 7 _S_ufficient_acreage_ayailable in drilling unit Yes 2560 acres. 8 if_deviated, is_ wellbore plat included Yes 9 Operator only affected party Yes 10 _Operator has_appropriate b_ond in force Yes Blanket Bond #6194193. 11 Permit can be issued without conservation order Yes Appr Date 12 _Permit can be issued without administrative app roval Yes ACS 12/4/2008 13 Can permit be approved before 154ay w ait Yes • 14 Well_located within area and strata authorized by Injection Order # (put IO# in comments) (For NA 15 _Ail welis_within 1/4_ mile_area_of review identified (For service well only) NA 16 Pre-produ_ced injector; duration_of pre-production less than 3 months (For ser_vice well only) NA 17 _N_onconverL gas_conforms to AS3_105.0306,1.A),(12.A-D) NA 18 Conductor string_provided NA Conductor set in 2-30/009 (191-114). Engineering 19 Surface casing_protects all known IJSDWS NA No U$DW's, A10 19, Conclusion 3. 20 _C_MT_v_ol adequate to circulate onconductor & surf csg NA Surface casing set in 2-30/009. 21 _C_MT_v_ol adequate to tie-infongatring to su rf csg NA Intermediate casing set in 2-30/009. 22 CMT_will coverall kno_w_n_productive horizons Yes New liner will be cemented ba ck into window. 23 Casing designs adequate for C,_T_, BA_ permafrost Yes 24 Adequatetankage_ dr reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well(s). 25 AEI re-drill, haea10403 for abandonment been approved Yes 308-436 26 _Adequate_w_ellbore separatio_n_proposed Yes Proximity analysis performed. Nearest segments are P&A portions of prior wells. Paths diverge. 27 _If_diverter required, does it meet regulations ILIA BOP stack will alread be in place. Appr Date 28 _Drilling fluid_ program schematic_itt equip listarlequate Yes Maximum expected formation pressure 9.3 EMW. MW planned up to 10.5 -PP9. BOs othey t regulation mee regulao TEM 12/12/2008 29 PE , - d - - Yes 30 _BOPE_press rating ap_propriate; _test to_(put psig in comments) Yes MASP calculated at 3907 psi, 4000 psi BOP testpla ' • 4'....' 31 _C_holie_ manifold compliee w/API RP-53 (May 8 4) Yes 32 _Work will occur without_operation shutdown Yes 33 is presence of H2S gas probable Yes H2S is reported at Endicott. Mud should pre_clucle H2S on rig. Rig_ has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o_ hydrogen sulfide measures No Endicott MPI is a H2S site. Max level H28 is 1300ppm on 2/14/07. Geology 36 _D_ata_p_resented on potential overpre zones NA Appr Date 37 _Seismic_analysis of shallow gas_z_ones NA ACS 12/4/2008 38 Seabed condition survey (if off-shore) NA 39 _C_ontact_name/pho_ne for weeldy_progress reports [exploratory only] Yes Dave Johnson - 564-4171. Geologic Engineering Public Date: Date Date Commissioner: Commissioner: Comairo;,ner • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of information. 1 Company BP Exploration (Alaska), Inc. Schiumberger Well Name 2- 30B /ME -01 1 ' Field Name Minke 1 State Alaska 1 Unique Well 50- 029 -22228 1 Identification Engineer's Name J.Lundberg rx Report Date 3/31/2009 \� I DCS Log Analyst: R.Heath 0 1 StethoScope 075 Final Report Innovations in Formation Testing PD Plot 7 Ver 7.1 56 1 1 Page Report Cover Written Comments 3 Formation Tops Table 4 Pressure Gradients 5 1 Mud_Column_Pressure Gradients 6 Test Point Summary Table 7 Test Point Table 8 Header 14 Hook Load During Test 15 Gauge Comparison Table 17 Inclinometry Tables 18 Well Path Plots 21 Pressure Vs Depth Plot 22 1 Time and Date vs. MD 23 XY MUD Before vs MUD After 24 Polaris Interpretation 25 1 1 1 1 I 1 Written Comments Schlumberger Objective: 1 Compile a StethoScope evaluation report that includes plots of formation pressures versus depth, fluid gradients, a table of test point data, and individual plots of each test draw - down /build -up sequence. 1 Comments: I Run 2 was conducted with the StethoScope 675 tool between 07- Mar -2009 and 08- Mar -2009 in the 8.5" hole, from approximately 13,790 ft to 14,140 ft (Measured Depth). I A total of 34 tests were completed with normal results on all but one test (Test #20 - Dry). Overall, the quality of the tests was very good - see the field engineer's comments on specific tests in the Test Point Table. The test quality is graded by color, with Green being the highest (see the attached table for grading I explanation). The majority of the tests were acquired using the Time Optimized Pretest (TOP) 2 -C sequence, as noted in the Test Point Table. The data used to generate this report was the Recorded Mode StethoScope data, 1 processed using PD -Plot software (Vers 7.1.56). TVD depths were calculated using the survey data supplied by the field engineer, in a report dated 1 03/08/09: 2- 30- ME- 0- 1_Final_Survey.txt. The Log Header shown in the report identifies the Field Name as "Endicott" from the data available at the time of logging; the actual Field Name should be "Minke ". The GR curve shown for correlation was obtained from the EcoScope tool. 1 1 1 1 1 1 1 1 1 1 1 2- 30B /ME -01 3 Schiumberger 1 Formation Tops Table 1 Formation Tops Table Source Customer Formation Tops j MD (ft) TVD (ft) Sub Sea (ft) Color TSGR 13779.75 9809.5 -9761 TSGA 13835.16 9862.5 -9814 TSHU 13856.07 9882.5 -9834 USS 13926.08 9949. -9901 UMSH 13995 10015.5 -9967 MSS 14031.52 10050.5 -10002 LMSH 14057.61 10075.5 -10027 LSS 14077.44 10094.5 -10046 TKVK 14156.75 10170.5 -10122 W eIITD 14211.01 10222.5 -10174 II 1 1 1 I 1 1 1 1 1 1 1 2- 30B /ME -01 4 ' Schlumberger Pressure Gradients Formation Gradients Formation Gradient Gauges Gradient Density j Gradient Contact Contact i Top ft Error % psi /ft g /cc i Caption Depth ft Caption Formation Pressure Lines ' UMSH,MS 3% AQAP 1 0.451 1.040 0.451 r 9952.29 S,LMSH,L (0.437 to psi /ft SS,TKVK 0.465 (Water) Psi /ft) TSGA, 9.3% AQAP 0.405 0.934 0.405 9832.52 TSHU (0.367 to psi /ft 0.443 (Water) psi /ft) Formation Gradients _ ' Base or RI STD psia Comment Contact ft Formation Pressure Lines 10129.22 0.9946 1.8200 T ! 0.8508 1.6400 1 I I I I 1 I 2- 30B /ME -01 5 Schlumherger I Pressure Gradients Mud Column Gradients I Formation Gradient Gauges Gradient Density Gradient Top ft Base or RI Error % psi /ft lb /gal Caption Contact ft Mud After Lines 2% AQAP 0.795 15.296 0.795 9823.79 10146.58 0.9595 (0.778 to psi /ft 0.811 psi /ft) I Mud Column Gradients STD psia I Comment Mud After Lines 16.1200 1 I 1 1 I I I 1 1 I 1 I 1 2- 30B /ME -01 6 I Schiumberger Test Point Summary Table I I Test Types Quantity Type 1-B 4 Type2-C 29 I Dry Test 1 TOTAL 34 1 Gauges i AQAP 34 I Runs Color 2 34 Formation Pressure Quality: Color I 0 (no pressure) - 10 (best) 10 30 7 3 0 1 I Drawdown Mobility Quality: Color 0 (no pressure) - 10 (best) 10 - - 111111 30 7 _ 3 I 0 - I 1 I I I I I I I I I I 2- 30B /ME -01 7 Schlumberger Test Point Table ( i >qv. L 1 est -F + t Ora n+d Formatio Forma Test Test Test Test Test Format Last-Rea p FPWD.Quality n on d 1 . No. TVO MD Subsea Type" Pressure taradien'Buildup : BuNdup Mobilit Invest. y ■ ft ft ft psia psitft psis psia mdtep 33 9823.79 13794.69 - 9775.29 Type normal test,mud cake ok,Small 4692.01 0.476 4691.38 4693.07 3.64 2 - C pressure variance; small slope,< 1/3 ;Build up I 32 9832.52 13803.82 - 9784.02 Type normal test,mud cake ok,Small 4680.71 0.475 4680.71 4679.96 13.05 I 1 2 - C pressure variance; small slope,< 1/3 Build up 1 9834.04 13805.41 - 9785.54 Type normal test,possible mud Ieak,Small 4683.88 " 0.475 4683.83 4683.97 9.01 I (((( 2 - C pressure variance; small slope,< 1/3 ! Build up i 31 9840.97 13812.65 - 9792.47 Type normal test,mud cake ok,Small 4687.58 0.475 4687.58 4687.63 4.17 2 - C pressure variance; small slope,< 1/3 Build up 30 9847.77 13819.76 - 9799.27 Type normal test,mud cake ok,Small 14689.05 0.475 4689.05 4687.72 32.38 2 - C pressure variance; small slope,< 1/3 ' Build up ' 29 } 9851.67 113823.83 - 9803.17 Type normal test,mud cake ok,Small - 14689.09 0.474 14688.35146 4689.5 25.61 i 1 - B pressure variance; small slope,< 1/3 Build up ° 27 9868.22 13841.131- 9819.72 Type normal test,Supercharging 4922.55 0.497 4922.55 5983.08 0.16 I 1 - B suspected,mud cake ok,Decreasing pressure variance; decreasing 1 i positive slope, not stabilized 28 19868.94 113841.89 - 9820.44 Type normal test,mud cake ok,Small 4748.01 0.48 4745.35 4747.05 6.09 ' 1 - B I pressure variance; small slope,> 1/3 I I Build up & <= 2/3 Build up 26 1 9873.35 13846.50 - 9824.85 Type normal test,mud cake ok,Small : 4716.99 ; 0.476 4717.49 4717.7 6.06 1 1 - B I pressure variance; small slope,< 1/3 Build up 1 2 9875.53 13848.78 - 9827.03 Type 1 normal test,mud cake ok,Small 4749 93 ; 0.479 4749.93 4751.19 1.32 2 - C ' pressure variance; small slope,< 1/3 I Build up I 34 9876.74 [13850.04 - 9828.24 Type normal test,mud cake ok,Small 4766.03 0.481 4766.03 1 4770.45 0.97 t 2 - C i pressure variance; small slope,< 1/3 i Build up 25 9878.86 13852.26 - 9830.36 Type normal test,mud cake ok,Decreasing 4785.59 ; 0.483 4785.59 3890.31 0.07 I 2 - C pressure variance; decreasing positive slope,> 2/3 Build up I 24 1 9952.28 [ 13929.00 - 9903.78 Type ; normal test,mud cake ok,Small 4612.11 0.462 4612.114611.61 0.97 1 2 - C pressure variance; small slope,< 1/3 I Build up 23 [ 9959.52 i 139361881-9911.02 Type 1 normal test,mud cake ok,Small 4612.63 0.462 4612.63 4612.54 3.9 I 2 - C 1 pressure variance; small slope,> 2/3 i Build up 22 9963.61 13 Type normal test,mud cake ok,Small 4613.53 0.462 4613.53 4613.46 139.9' 2 - C I pressure variance; small slope,< 1/3 ! 'Build up i 20 9969.79 - I - 13947.29f - 9921.29 , Dry i bad test,dry test 1 i 179.28 - 496.06 I ........ J i Test 1. _. ._ ...1..... _.... 2- 30B /ME -01 8 1 I Schlumberger Test Point Table , D r a w d a Sphed Preto Tune Format wn, Press FPW[ 60; Mud mud ! Egcd " Mod Ham cal . P acker Time Temp Prete Prete After an Mob SloPe Before- , After ' er Mobility. Whitt Probe Date After Time Dr�li To lr�v8st zit Variar , Density . Y n9 P mdtcp psia Asia/ psia lb/ga! psia md.ft/cp mdicp DEGF cc ___l_s cc/s hr I .. mlri 3.2 , 1.12 0.01 5764.05 11.261 5761.31 15.02 TST675 08-Mar -2009 142.57 11.6 j 11.631 1 25.51 I TSGR 1 Probe 01:03:31 �� i 15.38 0.87 0.09 5784.74 11.294 5783.7 j TST675 08-Mar-2009 142.5 7.33 7.31 1 f 213TSGR I Probe 00:45:10 I 10.11 0.56 - 676 - 6158 1 4 - 7 - .0 1 8 - 111.396 1 5836.67 12.06 TST675 07- Mar -2009 143.58 7.53 7.511 3.27 I TSGR Probe 02:54:15 i [ 1 i I 4.58 0.48 1 5776.86 11.275 5778.9 TST675 08-Mar-2009 142.36 8.04 ; 8.06 1 24.68 TSG Probe 00:23:00 I 1 53.01 10.53 4.28E 5753.67 11.219 I 575426 TST675 142.43 7.36 ' 7.31 1.01 24.15 TSGR I -03 i 1 Probe 23:54:41 1 - 30 - .4 4 109 1 0 . 13 1 5758 . 611 . 219 L 75626 1 144.03 19.06 TST675 07- Mar -2009 142.63 7.47 i 7.5 1 23.8 TSGR Probe 23:35:51 i 174.07 1 0.53 , 9.63 5788.891 11.256 5784.94 TST675 07- Mar -2009 143.37 4.12: 13.94 0.3 22.32 , TSGA Probe , 22:48:21 I : 6.07 0.62 0.38 5784.08 j 11.251 5782.87 1 1.51 TST675 07- Mar -2009 142.97 7.44 7.44 - 1 - 1 1 22.72 ! TSGA i !!! Probe 23:12:01 5.89 2.53 0.46 5811.94 11.292 5806.58113.75 1:- ----f- }-L TST675 07- Mar -2009 143.98 7.56 17.56 1 121.68 Probe 22:14:02 s _�_._.__ _ ®_._ � ._.._,_, _.._._....._. 1.07 0.5 i -.12 5766.93 � 11.212 i 5766.46 i TST675 07- Mar -2009, 144.82 2.45 13.8 TS+ Probe 04:06:43 _ I 1 I 0.82 0.4 : 1746 I 5794.771 11.263 5793.36 i TST675 08-Mar -2009 142.74 3.12 1 6.38 1 0 .49 25 I TSGA Probe 01:34:31 3 1 4 1 TST675 07- Mar -2009 1 44.72 0.53 1.25 ' 47 5837.9 , �______ _.. __ 10.42 21.02 TSGA I 0.59 0.78 ! -1.29 5842.09 11.3 1 I I 1 Probe 21:38:04 I 1 , I ..._... .._.. i ........_._._._ ...__. _. 4.44 0.54 17.42 ` ._ _ .._ 07 Mar -2009 14477 241 0.95 : 0.87 0.03 - 15886.51111.354 5884.59 TST675 .. U$S r i I I Probe 21:05:04 1 , I 3.26 2.2 1 TST675 07- Mar -2009 14418 ' 1 i 16.97 U$$ I I Probe 20:44:14 1 I I 123.42 ' 0.17 -.02 1 5883.61 11.339 15883.531 TST675 07- Mar -2009 145.02 7.37 17.38 , 1 1 16.52 i U8S 1 ; Probe ' 20:22:05 f , - 10.03 21.02 5891.53111.345 . TST675 07- Mar 2009 144.7 3.04 10.13 0.3 1 14.8 USS I 1 I t Probe ` 19:10:58 1 __ .__ _ ; I 2- 30B/ME -01 9 Schlumberger Test Point Table I q v. 1 Formato Formati Last-Rea L t-Rea ?rawd Test Test' Test Test Test ... d own FPW,D. Quality n on d No. ,TVD MD Subsea - Type - 8udup - Mcili 1 Pressure Gradien Buildup . invest. y I ft 1 ft ft psis psi/It psaa psis and /cp 21 f 9971.41 13948.97 - 9922.91 Type normal test,mud cake ok,Small 4617.15 0.462 4616.16 4616.82 22.65 2 - C ; pressure variance; small slope,< 1/3 Build up 19 19978.91 t 13956L9930.41 Type 1 normal test,mud cake ok,Small 4619.67 0.461 t4 4618.99 5.52 2 - C l pressure variance; small slope,< 1/3 ; Build up 18 9984.08 13962.21 - 9935.58 Type normal test,mud cake ok,Small 4623.36 0.462 4623.36 4622.1 3.8 2 C pressure variance; small slope,< 1/3 , ( Build up 17 f9995.3 1 Type normal test,mud cake ok,Small 4626.63 0.461 4626.63 4626.52 782.6' 2 - C I pressure variance; small slope,< 1/3 1 ' Build up 1 16 9999.05 Type normal test,mud cake ok,Small 4628.53 0.461 4628.53 4628.04 5.37 2 - C pressure variance; small slope,< 1/3 1 ' I Build up '.. 15 110005.15[13984.20 - 9956.65 Type I normal test,mud cake ok,Small 4631 0.461 4631 4630.8 25.09 i i ' 2 - C , pressure variance; small slope,< 1/3 € ( I Build up 1 14 10022.2 14002.001-9973.70 Type l normal test,mud cake ok,Small 4644.24 ' 0.462 4644.24 4644.21 6.88 2 - C ; pressure variance; small slope,< 1/3 I Build up 1 13 10053.01 14034.15 - 10004.51 Type normal test,mud cake ok,Small 4660.07 0.462 4660.07 4658.55 13.96 2 - C pressure variance; small slope,< 1/3 1 Build up 12 10056.7 i 14038.00 - 10008.20 Type normal test,mud cake ok,Small 1 4656.1 6 ; 0.462 4656.23 4655.92 30.5 2 - C ; pressure variance; small slope,< 1/3 Build up I ii 11 ; 10058.62 j 14040.00 - 10010.12 Type Tnormal test,mud cake ok,Small I 4 6 56 . 3 0.461 1 4656.25 4655.98 63.82 II 2 - C pressure variance; small slope,< 1/3 , Build up I I 10 10061.481 14042.99 - 10012.98 Type I normal test,mud cake ok,Small 4 7.11 � 0.461 4657.11 4656.97 49.8 1 I 1 2 - C ' pressure variance; small slope,< 1/3 Build up I 9 10064.39 14046.03 - 10015.89 Type normal test,mud cake ok,Small 4657.37 0.461 1465737 4657.43 149.2 1 2 - C Ipressure variance; small slope,< 1/3 �___ ._. € 1 Build up 8 x10067.01 114048.76 Type normal test,possible mud Ieak,Small 4660.94 4661.44 6.25 2 - C E pressure variance; small slope,< 1/3 { 4661.440.462 ( Build up I 7 110070.24 14052.13 - 10021.74 Type normal test,mud cake ok,Small 4660.82 0.461 4660.82 4660.36 132.:: i 2 C p variance; small slope,< 1/3 i I ; Build up 1 1 6 t 10102.83 14086.13 - 10054.33 Type , normal test,mud cake ok,Small ` 4676.49 0.461 r4494677.21 22.58 I 2 - C ` pressure variance; small slope,< 1/3 ; , Build up ' 5 10117.78 1 14101.73 - 10069.28 Type I normal test,mud cake ok,Small 4683.75 0.461 4683.75 4683.22 36.03 ' 2 - C I pressure variance; small slope,< 1/3 I Build up 1 2- 30B /ME -01 10 1 I Schiumberger Test Point Table I rawdo „,,, c ,„ Spheri Format wn" j o t -7: 608 Mud ki * -4 _, -- Mud Homer oal Packer Time & Temp Prete Prete Prete 11 " Slope Before nnuu . After Mobility Mobilit Probe Date After st After,' 011 1 I Invest Varier Deneit y Time Diiiing Top ald/cP psia psia/ psia Titgai psia red iticp mci/cp DEGF r.. s cc/s hr I 42.87 1 0.45 0.01 5904.58111.37 5904.05 24.94 TST675 07-Mar-2009 145.13 7.37 7.44 0.99 15.41 Probe 19:48:58 I 4.58 0.45 -.01 5906.7 11.36615906.69 TST675 07-Mar-2009 1441-644-11-7.35 1- 7.31 1.01114.22 USS Probe 18:44:38 1 , I I ----- - 378 9 - 0.57 0.04 5911.07 11.371 5912.441 TST675 07-Mar-2009 144.81 7.51 7.56 , 0.99 13.82 1 Probe 18:24:49 ! 1 I 1 I 594 5904.95 -03 TST675 07-Mar-2009 144.77 7.37 7.341 113.38 US$ Probe 18:04:39 I 5.57 - 10.82 -.08 5901.87 11.328 5898.69 --- TST675 07-Mar-2009 144.68 7.35 12.93 I ‘ Probe 17:42:49 , .._ 4 38.59 0.13 0.01 5906.76 I 11.331 5903.99 , TST675 07-Mar-2004144.72 F 15 1.13 12.4 USS I , 1 6.ii 0.ii 0.01 5925.1 I 11.35 5923.77 Probe 17:18:02 TST675 07-Mar-2009 144.73 7.42 7.44 1 11.73 1 utteH Probe 16:57:52 I 4.34 0.54 10704 5939.55 11.3485941.04 TST675 07-Mar-2009 144.66 7.57 7.44 1.02 10.42 MSS Probe 16:36:03 1 I I 33.27 0.24 I 0.05 5926.451 11.318 , 5927.77 25.65 TST675 07-Mar-2009 144.75 7.53 7.56 1 10.06 M$S Probe 16:16:33 • 1 1 1 1 I I 56.24 liiid0.02 5935.32111.327 I I 31.3 TST675 07-Mar-2009f144.84 7.54 7.5 1.01 9.68 MSS Probe 15:55:03 1 ,1 63.42 0.15 10105 11.344 5943.85 TST675 07-Mar-2009 145.17 7.541 1 9 MSS I I • 1 I Probe 15:15:43 132.73 0.16 -1.23 5947.1 1 11.343 5945.27 1 TST675 07-Mar-2009 145.6 , 7.35 7.38 1 8.45 MSS I E-03 I I -1 Probe 14:43:54 1 7.04 1.31 0.05 5951.62111.352 5951.23 I TST675 07-Mar-20091 145.83 7.31 7.31 1 7.9 MSS f I 1 I Probe 14:13:22 I 98.74 10.13 0.02 5957.09 11.357 5955.621 1 I - 1 - I TST675 07-Mar-2009 146.1 7.56 11 7.52 t MSS 1 1 Probe 13:51:43 i 1 . I 26.32 - 1 - 0.3 10.04 5987.15111.372 5982.73 , 1 TST675 07-Mar-2009I 146.39 7.33 7.38 1 0.9916.561LSS I Probe 13:25:52 I 1 I 43.15 0.37 0.1 , 5984.23 5983.56 I I I TST675 07-Mar-2009 146.86 [7.33 7.38 {0991 01 I Probe 13:00:52 I I 1 I I I 2-30B/ME-01 11 Schlumberger Test Point Table I Equiv. Last -Rea Drawd Test Test Test Test Test Formatio Formats ; ! V ast flea ,d own No. TVD MD Subsea Type FPWD Quality n on d Buildup Mobiiit ' 1 Pressure Gradien Buildup invest y t 1ft ft ft psis psi/ft psis. Asia and /cp 4 1 14113.67 Type o normal test,mud cake ok,Small 4687.98 0.461 4687.98 4688.21 63.31 2 - C pressure variance; small slope,< 1/3 i I Build up 3 10146.58 14131.781-10098.08 Type normal test,Supercharging 4705.52 0.462 4705.52 3973.69 0.09 2 - C suspected,mud cake ok,Small pressure variance; small slope,> 1/3 1 Build up & <= 2/3 Build up i € 1 1 1 1 1 1 1 1 1 1 1 1 1 2- 30B /ME -01 12 1 I Schlumberger Test Point Table I CQrawdo; :. Spheri i . j FPWt E t it Prete Time I Format wn 60 $ . Mud M v. Mud Homer cal Packer Time & Temp Prete st Prete After on Press op Mobility Time Dr�lirrg Top # Mob Slope Before Alter Mobilrt Mobil Probe Date Atter Invest Varier - -- 17ensity Y _ md/cp peia- pale/ Psia h b/gal pi is mdittcp, mdtcp ,, DEG1= cc $ . cc/s hr I 59.02 0.21 -2.72 15992.19 11.362 5993.41 ! TST675 07-Mar-2009 147.67173 7.38 1 5.06 LSS E -03 Probe 12:36:52 I 1 I I 0.67 0.78 1 0.11 1004ul1ll.3646O0467i TST675 07- Mar -2009 149.56 0.52 1.25 ; 0.42 1 4.43 L $. Probe 12:12:52 I I I I I I I I I I I I 2- 30B/ME -01 13 Schlumberger Header 1 COMPANY: BP Exploration (Alaska), Inc. WELL: 2- 30B/ME -01 1 FIELD: Endicott Borough: North Slope State: Alaska Schlumberger 1 U 1C3 K.B. 0 ft o a G.L. 13.4 ft co a o W c D.F. 48.5 ft z ° W N m .� Permanent Datum: Elev: 0 ft 0 J Log Measured From: Driller Floor 48.5ft above Perm. Datum Drilling Measured From: State 0 o u b E CO ° i .3 o 36 T12N R16E Logging Date Run Number 1 Depth Driller 0 ft Schlumberger Depth 0 ft Bottom Lo. Interval 0 ft Top Lo. Interval 0 ft Casing Drilling Size @ Depth 0 in 0 ft Casing Schlumberger 0 ft Bit Size 8.5 in Type Fluid in Hole LSND I Density Viscosity 10.5 lb/gal 15 cp Mud Fluid Loss PH 3.3 ml 9 Source of Sample I RM @ Measured Temperature 0 @ 0 DEGF @ RMF @ Measured Temperature 0.36 @ 102 DEGF @ RMC @ Measured Temperature 0 @ 0 DEGF @ Source RMF Source RMC RM • MR RMF • MRT 0 0 DEGF 0 0 DEGF - - -- Maximum Recorded Temperatures 0 DEGF 0 DEGF 0 DEGF Circulation Stopped Time Logger On Bottom Time Unit Number Location - Recorded By J.Lundberg Witnessed By D.Messer 1 2- 30B /ME -01 14 t I Schlumberger test I FPWD Test Hookload Sheet I I T I Hookload . Kibs 100 150 200 250 300 350 I 13750 • 3 1 13800 * • * i 13850 I 1 13900 ' • Q13950 I • 14000 I LI 1 14050 I 14100 kg 1 14150 7 Depth PU SO 1 Test Depth 1 Test Wt I 13858 280 1190 1 13795 240 I 1 13867 280 190 13804 240 L 13869 280 190 13805 240 I 13876 280 190 13813 240 13883 280 190 13820 240 1 13887 280 190 13824 240 13905 280 190 13841 240 I 13905 280 190 13842 240 13910 280 190 13847 240 I I 13912 290 190 13849 235 1 1 I I 2- 30B /ME -01 15 Schlumberger test 13913 280 190 13850 240 - 1 13916 1 290 1 13852 1 240 1 - - - - 1 1 1 13992 290 190 13929 240 1 14000 1300 1 190 13937 240 14004 1 300 1 190 1 13941 j 245 1_ - -- 14011 1290 200 13947 245 14012 1 290 200 1 - 13949 245 290 2 14020 � 200 13957 245 I A 14026 290 200 13962 245 14037 290 200 13974 245 1 14041 290 1. 13978 245 - 1 14048 290 200 13984 ', I 245 - - T 1 �� I� ,14065 290 200 14002 245 i 1 f 14098 1 280 ,200 14034 245 1 14101 290 200 14038 250 ] 14103 290 200, 14040 250 14106 1 300 205 1 14043 250 1 1 1- 1 - 14109 300 205 14046 250 14112 300 1205 14049 250 Th 14116 300 1 205 1 14052 250 14150 300 205 14086 250 14165 300 1 205 14102 250 Down Weight is RED _ 14177 300 205 14114 1 250 f 7 Up Weight is BLUE 1 7 1 I 1 T 14195 300 205 r 14132 245 1 J Test Weight is BLACK, I I I I 2- 30B /ME -01 16 I I Schlumberger Pressure Gauge Comparison Table I r File Test Test . 1 Test Farmedurf Mud Mu No. No. TV17 Subsea Pressure Before ` After Test Type (ACtAP) (ACIAP) . (AQAP) �_ 0 33! 13795 - 9775.29 4692.01 5764.05 5761.31 Type 2 - C I 0 32 13804 - 9784.02 4680.71 5784.74 5783.7 Type 2 - C O 1 13805 - 9785.54: 4683.88 5847.38 5836.67 Type 2 - C MO 31 13813. - 9792.47 4687.58 5776.86 5778.9 Type 2 - C mom I 30 13820 - 9799.27 4689.05 5753.67 5754.26 Type 2 - C 0 29. 138241 - 9803.17 4689.09 5758.6 5756.26 Type 1 - B O 27 13841 - 9819.72 4922.55 5788.89 5784.94 Type 1 - B I 0 28 13842 -9820.44 4748.01 5784.08 5782.87 Type 1 - B O 26 13847 -9824.85 4716.99 5811.94 5806.58 Type 1 - B 0 2 13349,, . - 9827 4749.93 5766.93 5766.46 Type 2 - C ' 0 34 13850 - 9828.24 4766.03 5794.77 5793.36 Type 2 - C 0 .. 25 13852 - 9830.361 4785.59 5842.09 5837.9 Type 2 - C 24 13929 ' - 9903.78 4612.11 5886.51 5884.59 Type 2 - C I 0 23 13937 9911 02 4612.63 5895.35 5897.02 Type 2 - C 0 - 22, 13941 - 9915.11 4613.53 5883.61 5883.53 Type 2 - C 0 20! < '13947 9921.29: 5891.53 5890.59 Dry Test I 0 21 13949 - 9922.91 4617.15 5904.58 5904.05 Type 2 - C 0 19 13957 - 9930.41 4619.67 5906.7 5906.69 Type 2 - C .0 18 13962' - 9935.58 4623.36 5911.07 5912.44 Type 2 - C 1 0 17 13974 . - 9946.80 4626.63 5903.44 5904.95 Type 2 - C 0 16 139 - 9950.55 4628.53 5901.87 5898.69 Type 2 - C 0 15' 13984 - 9 4631 5906.76 5903.99 Type 2 - C I 0 14 140021 9973.70 4644.24 5925.1 5923.77 Type 2 - C 0 13 14034 - 10004.51 4660.07 5939.55 5941.04 Type 2 - C 0 12, 14038! - 10008.20 4656.16 5926.45 5927.77 Type 2 - C I „0 11 14040 - 10010.12 4656.3 5935.32 5933.24 Type 2 - C O 10 14043 10012.98 4657.11 5946.35 5943.85 Type 2 - C 0 9 ' 14046 - 10015.89 4657.37 5947.1 5945.27 Type 2 - C I 0 8 14 10018.51 4661.44 5951.62 5951.23 Type 2 - C ' 0 ' 7 1 40521 - 10021.74 4660.82 5957.09. 5955.62 Type 2 - C 0 6 140861 ; 10054:33 4676.49 5987.15 5982.73 Type 2 - C I _ °` 5 14102 -10069.28 4683.75 5984.23 5983.56 Type 2 - C 0 4 _14 10080.72 4687.98 5992.19 5993.41 Type 2 - C 0 3 141321 - 10098.08 4705.52 6004.11 6004.67 Type 2 - C I ' . Gauge Specifications_ i - - __ -- - -_ -- r ' I Pressure Accuracy' Repeatability Resolution I Gauge, Name Range ,;, {p�} {psi) (p) Module Symbol AQAP (Quartz) 0 - 15000 +/_5.0000 +/- 0.5000 J 0.0400 FPWD 0 I I I 2- 30B/ME -01 17 Schlumberger I Inclinometry Tables 2- 30B /ME -01 I Source :Supplied Survey table MD TVD Devi ( Azimuth ' North ' East Departur ; Departur Dogleg e e Severity 1 Azimuth ft ft Deg Deg ft ft ft Deg Deg /100f 0.00 0.00 0.00 0.00 , 0.00 0.00 0.00 0.00 ' 35.10 35.10 0.00 0.00 0.00 0.00 0.00 0.00 93.17 93.17 0.33 29.37 0.15 0.08 0.17 28.07 193.17 1 193.17 0.02 - 182.17 0.38 0.22 _ 0.44 30.07 0.31 293.17 [ 293.17 0.06 147.59 0.32 0.25 0.41 138.00 0.04 393.17 393.17 0.08 117.96 0.24 _ 0.34 0.42 54.78 0.02 - 493.17 493.17 0.12 38.51 r 0.29 0.47 0.55 58.32 0.04 593.17 593.17 0.45 314.72 0.65 10.25 0.70 121.04 f 0.33 693.17 693.16 _ 0.95 I 332.10 1.66 -0.41 1.71 346.13 0.50 793.17 793.13 1.92 326.02 3.78 -1.74 1 4.16 335.28 0.97 893.17 893.02 3.27 , 338.95 7.83 -3.70 8.66 334.71 ' 1.35 3.04 326.97 - 18.50 - 8.98 � 20.56 I 993.17 992.84 3.69 _ 334.08 13.39 6.13 14.73 0 0.42 1 335.4 1093.17 1092.67 334.11 0.65 1193.17 1192.56 2.28 313.96 22.11 -11.86 25.09 331.79 0.76 1293.17 1292.50 1 1.74 316.06 24.58 -14.34 2 8.46 329.74 0.54 1393.17 1392.46 r 1.36 316.36 26.53 -16.22 31.10 328.56 0.38 1493.17 _ 1492.44 1.21 318.15 28.18 -17.74 _ 33.30 4 327.81 0.15 1593.17 1592.42 1 0.94 328.25 29.66 -18.88 35.16 I 327.52 0.27 1693.17 1692.41 0.73 319.38 30.84 -19.72 36.61 327.40 0.21 1893.17 1892.39 0.80 324.72 31.90 - 20.54 , 37.94 327.22 0.07 1793.17 1792.40 f 0.64 312.25 32.84 -21.36 39.18 326.96 0.16 1993.17 1992.39 I 0.52 301.92 33.46 -22.16 40.13 326.48 0.12 2093.17 2092.38 0.31 300.76 33.84 -22.77 40.79 326.06 0.21 I 2193.17 2192.38 0.36 273.90 34.00 -23.32 41.23 325.55 0.05 2293.17 2292.38 0.16 165.26 33.88 -23.60 41.29 325.14 0.20 2393.17 2392.38 0.32 144.74 - 33.52 -23.40 40.88 325.08 0.16 2493.17 2492.38 0.42 _ 165.08 32.94 -23.15 40.26 324.90 0.10 _ , 2593.17 2592.38 0.35 197.45 32.29 -23.14 39.73 324.37 0.07 2693.17 2692.37 0.25 221.05 31.84 - 23.38 39.50 323.71 0.10 2793.17 2792.37 0.15 244.73 31.62 23.64 39.48 323.22 0.10 I 2893.17 2892.36 1.30 340.26 32.63 -24.14 40.59 323.51 1.15 2993.17 2992.27 3.50 - 342.73 36.61 -25.43 1 44.58 325.22 - 12.20 3093.17 3092.00 4.94 344.48 43.67 -27.49 51.60 1327.81 1.44 3193.17 3191.51 6.40 343.10 53.16 -30.26 61.17 330.35 1.46 I 3293.17 3290.75 7.66 340.94 64.79 -34.06 73.20 332.27 1.26 3393.17 3389.68 9.10 333.68 78.18 -39.74 87.70 333.06 1.44 3493.17 3488.22 10.52 1 327.24 92.94 _ -48.19 104.69 332.59 1.42 3593.17 3586.33 11.83 319.16 108.38 -59.83 123.80 331.10 1.31 3693.17 3683.92 13.35 319.14 124.86 -74.09 145.19 t 329.32 1.52 3743.17 3732.47 14.38 319.44 133.95 -81.90 157.00 328.56 2.06 3793.17 3780.80 15.26 320.30 143.73 -90.14 169.66 327.91 1.76 3843.17 3828.96 15.91 1319.81 154.02 -98.77 182.97 327.33 1.30 3893.17 3876.97 ' 16.55 319.19 164.65 - 107.85 196.83 326.77 1.28 3943.17 3924.83 17.08 317.82 175.48 - 117.43 1211.15 1 326.21 1.06 H 3993.17 3972.58 17.43 L 315.86 186.30 - 127.58 225.80 325.60 _ 0.70 4043.17 4020.17 18.31 I 313.77 197.10 - 138.46 240.87 1324.91 1.76 4093.17 4067.16 21.61 313.22 208.85 - 150.85 257.63 - 324.16 6.60 4143.17 4113.18 24.37 1313.03 222.19 - 165.10 276.81 323.39 5.52 4193.17 4158.42 26.06 I 313.25 236.76 - 180.64 297.80 322.66 ,_3.38 I 4243.17 4203.00 27.77 313.24 252.26 - 197.13 320.15 321.99 3.42 4293.17 4247.10 28.48 312.95 268.37 - 214.34 343.46 321.39 1.42 4343.17 4290.66 30.30 313.05 285.10 - 232.28 367.74 320.83 3.64 4393.17 4333.54 31.58 313.41 302.71 - 251.01 393.24 320.33 2.56 4443.17 1 33.20 314.56 321.31 - 270.28 419.87 319.93 3.24 2- 30B /ME -01 18 I Schlumherger Inclinometry Tables I 4493.17 4417.18 34.94 315.11 341.06 - 290.14 447.78 319.61 3.48 4543.17 4457.67 36.92 315.33 361.89 - 310.80 477.03 319.34 3.96 4593.17 ! 4497.29 38.22 315.20 383.54 - 332.26 507.44 319.10 2.60 I 4693.17 4575.12 39.39 314.78 427.89 -376.73 570.10 318.64 0.78 4643.17 4536.37 39.00 314.85 405.62 -354.31 538.58 318.86 -- ,0.78- 4743.17 4613.86 39.03 314.73 450.14 -399.17 601.63 318.43 0.72 4793.17 4652.65 39.19 314.86 472.36 - 421.56 633.12 318.25 0.32 4843.17 4691.30 39.59 4893.17 4729.84 39.55 314.96 494.76 - 444.03 664.79 318.09 0.80 314.96 517.27 - 466.57 696.60 317.95 0.08 4943.17 1 4768.23 40.12 1 315.21 539.95 - 489.18 728.59 317.82 1.14 4993.17 4806.46 40.16 315.04 562.79 - 511.92 760.79 317.71 0.08 I 5043.17 4844.50 40.74 315.17 585.77 I - 534.82 793.20 317.60 ' 1.16 5093.17 4882.35 40.86 315.09 608.93 - 557.87 825.84 317.51 0.24 5143.17 4920.02 41.38 1314.87 632.17 - 581.13 858.69 317.41 1.04 I 5193.17 4957.42 41.79 5243.17 4994.60 42.14 314.62 655.53 - 604.70 891.84 317.31 0.82 314.40 678.97 1 -628.54 925.24 317.21 0.70 5293.17 5031.51 42.71 314.18 702.52 - 652.69 958.93 317.11 1.14 5342.17 15067.43 42.97 313.95 725.70 - 676.63 992.20 317.00 0.53 I 5393.17 5104.56 43.60 5443.17 5140.66 43.97 313.78 749.93 - 701.84 1027.12 316.90 1.24 313.51 773.81 I - 726.87 1061.66 316.79 0.74 5493.17 1 5176.53 44.35 1 313.39 797.76 - 752.16 1096.43 316.69 0.76 5543.17 5212.15 44.78 313.20 821.82 1-777.70 1131.46 316.58 0.86 I 5593.17 5247.55 45.08 312.96 845.94 - 803.49 1166.71 316.47 0.60 5643.17 5282.68 45.64 313.12 870.22 - 829.49 1202.22 316.37 1.12 5693.17 5317.61 45.72 313.13 894.67 - 855.60 1237.94 316.28 0.16 5743.17 5352.38 46.17 313.24 919.27 - 881.80 1273.82 316.19 0.90 I 5793.17 5386.94 46.38 313.25 944.02 - 908.12 1309.91 316.11 0.42 5818.00 5404.04 46.57 313.19 956.35 - 921.24 1327.89 316.07 0.77 5882.88 5447.62 49.05 317.10 990.44 - 955.11 1375.94 316.04 ' 3.82 I 5972.37 5504.55 51.96 321.44 1042.77 - 1000.10 1444.84 316.20 1 3.25 -1047.90 1521.26 316.46 2.95 54.78 321.49 1102.79 - 1 6067.98 5561.59 6165.55 5616.79 56.31 324.55 1167.05 - 1096.27 1601.19 316.79 1.57 6254.11 5665.10 57.58 325.82 1227.99 - 1138.64 1674.65 317.16 1.43 I 6348.43 5714.78 58.86 327.61 1295.02 - 1182.63 1753.76 317.60 1.36 6442.98 5763.36 59.30 326.50 1363.09 - 1226.74 1833.82 318.01 0.47 6536.39 5810.91 59.50 325.42 1429.71 i - 1271.75 1913.48 318.35 0.21 6631.70 5858.74 60.26 327.15 1498.28 - 1317.50 1995.16 318.67 0.80 I 6725.36 5903.21 63.05 329.16 1568.30 - 1360.97 2076.49 319.05 2.98 6819.94 5944.88 64.67 331.84 1642.20 - 1402.76 1 2159.76 319.50 1.71 6913.51 5985.39 64.03 330.45 1716.07 - 1443.46 2242.43 319.93 0.68 I 7007.14 6025.38 65.39 329.94 1789.53 - 1485.54 2325.78 320.30 1.45 7102.01 6066.05 63.84 330.27 1863.83 - 1528.26 2410.28 320.65 1.63 7196.72 6107.46 64.31 330.11 1937.74 - 1570.61 2494.32 320.97 0.50 7292.14 16149.19 63.82 329.93 2012.07 - 1613.48 2579.10 321.27 0.51 ' 7387.25 6192.03 62.64 7482.21 6235.44 62.95 329.56 2085.41 - 1656.27 2663.11 321.54 1.24 328.90 2157.98 - 1699.47 2746.83 321.78 0.33 7577.49 6278.38 63.48 328.70 2230.73 - 1743.54 2831.27 321.99 0.56 7671.57 6320.21 63.72 328.57 2302.69 -1832.16 2914.99 322.18 0.26 L 7767.40 6363.04 63.19 328.48 2375.80 1832.16 3000.21 1 322.36 0.55 - 7860.91 6404.12 64.69 329.43 2447.77 -1875.47 3083.66 322.54 1.60 7955.83 6445.59 63.50 330.32 2521.62 - 1918.33 3168.37 322.74 1.25 I 8050.79 6488.75 62.43 330.08 2595.02 - 1960.36 I 3252.25 I 322.93 1.13 8144.67 1 6532.13 4 62.52 329.88 2667.10 - 2002.01 3334.89 323.11 0.10 8238.44 6575.48 62.42 330.50 2739.25 - 2043.35 3417.42 323.28 0.11 8333.89 6619.33 62.88 329.72 12812.75 - 2085.60 3501.61 323.44 0.48 I 8430.18 6662.98 63.21 - 332.24 2887.80 2127.23 3586.71 323.62 0.34 8523.09 6704.98 63.04 333.83 2961.66 2164.81 3668.49 323.84 0.18 8618.71 6748.18 63.25 335.81 3038.86 - 2201.10 1 3752.27 324.08 0.22 8711.97 6789.35 64.36 334.80 1 3114.88 - 2236.06 13834.38 I 324.33 1.19 1 8806.04 6830.62 63.60 335.13 3191.47 - 2271.84 3917.49 324.55 0.81 8900.31 6872.47 63.68 333.60 3267.62 - 2308.38 4000.74 324.76 0.08 I 2- 30B /ME -01 19 Schlumberger I Inclinometry Tables 8994.68 1 6913.77 64.42 1 332.89 3343.39 I - 2346.58 4084.69 324.94 , 0.78 I 9089.51 6954.81 64.29 331.72 3419.09 - 2386.31 I 4169.49 325.09 0.14 9183.83 6996.68 63.00 331.46 3493.42 - 2426.52 4253.47 ` 325.22 1.37 9278.01 7039.45 62.99 330.72 3566.88 - 2467.09 4336.95 325.33 0.01 9373.11 7083.84 61.36 I 330.24 3640.06 - 2508.52 4420.71 325.43 1.71 9466.55 7128.12 62.06 329.82 3711.34 - 2549.62 - 4502.73 325.51 0.75 9561.57 7172.82 61.82 329.86 3783.84 - 2591.75 _ 4586.35 325.59 0.25 9654.11 7216.18 62.30 329.66 3854.46 - 2632.93 4667.89 325.66 0.52 9748.60 7260.59 61.63 330.77 3926.85 - 2674.36 4751.04 325.74 0.71 9844.33 7305.02 63.06 330.07 4000.58 - 2716.22 4835.54 325.83 1.49 9938.28 7348.27 62.12 1329.92 4072.81 - 2757.92 4918.73 325.90 1.00 10034.05 7392.60 62.74 329.53 4146.12 - 2800.72 1 5003.43 325.96 0.65 10128.57 7435.88 62.75 330.17 1 4218.78 - 2842.93 5087.27 326.02 0.01 10224.19 7480.15 62.10 330.58 4292.46 -2884.82 517 326.10 0.68 10318.72 7524.46 61.99 332.29 4365.79 -2924.75 ' 3 . 326.18 5254.93 326 012 10413.75 7569.15 61.91 331.97 4439.93 -2963.95 5338.35 326.27 0.08 I 10509.60 7613.79 62.57 1331.83 - 4514.75 -3003.90 5422.77 326.36 0.69 10602.93 7657.46 61.64 1332.23 4587.60 - 3042.59 5504.85 326.45 1.00 10697.88 7702.46 61.78 331.41 4661.30 - 3082.07 5588.10 1 326.53 0.15 I 10792.25 7746.84 62.11 331.17 4734.34 - 3122.08 5671.10 326.60 0.35 10887.12 7791.67 61.49 331.54 4807.72 - 3162.16 5754.43 326.67 0.65 10983.43 7837.15 '' 62.16 331.22 4882.24 - 3202.83 5839.04 326.73 0.70 1 11076.66 7880.53 62.38 332.42 4954.98 - 3241.80 5921.24 326.81 81 0.24 11171.15 7924.28 ' 62.46 1 331.68 5028.96 - 3281.05 6004.64 326.88 0.08 11266.14 7967.87 i 62.91 331.66 5103.25 - 3 60 1 326.94 0.47 - - - 11360.29 8010.42 63.35 331.84 5 177._2 -3360.85 6172.44 1327.01 0.47 I 11454.08 8052.08 63.90 331.24 5251.10 -3400.90 6256.21 327.07 0.59 11548.06 8093.61 63.66 329.73 5324.47 - 3442.43 6340.37 327.12 0.26 11643.02 8135.58 63.88 11 329.14 5397.82 - 3485.75 6425.49 1 327.15 0.23 11736.66 8178.15 62.04 329.93 5469.70 - 3528.04 ' 6508.82 1 327.18 1.96 11830.25 8223.92 59.40 330.99 5540.71 - 3568.29 6590.31 1327.22 2.82 11925.24 8274.79 55.82 331.77 5611.10 - 3606.71 6670.29 327.27 3.77 12018.33 8328.23 54.12 331.01 5678.02 - 3643.21 6746.32 327.31 1.83 12113.26 8385.12 52.23 331.49 5744.64 -3679.76 6822.13 327.36 1.99 I 12206.50 8444.79 48.17 331.58 5807.60 -3713.89 6893.56 327.40 4.35 12302.23 8510.13 45.75 330.72 5868.88 - 3747.64 6963.37 327.44 2.53 12397.01 8577.86 43.01 330.35 5926.59 - 3780.24 7029.56 327.47 2.89 12490.88 8648.06 40.17 328.77 5980.32 -3811.78 327.49 3.03 12584.78 8720.88 38.12 329.37 6031.16 - 3842.26 7151.07 327.50 2.18 12680.13 8797.26 35.42 331.33 6080.74 - 3870.51 7208.07 327.52 2.83 - - - 12772.44 8874.20 31.63 329.27 6125.03 -3895.73 7258.97 327.54 4.11 I 12866.98 8956.00 28.52 329.77 6165.85 -3919.76 7306.31 327.56 3.29 12961.06 9039.52 26.29 331.00 6203.48 - 3941.17 1 7349.56 327.57 2.37 13055.85 9125.49 23.50 331.21 6238.41 - 3960.46 7389.38 327.59 2.94 13151.23 9213.87 20.67 1 331.92 6269.94 - 3977.54 7425.16 327.61 2.97 13244.35 9301.33 19.48 332.02 6298.15 - 3992.56 7457.03 327.63 1.28 13338.97 9390.65 19.06 332.74 6325.82 - 4007.04 7488.15 327.65 0.44 13433.57 9480.45 17.56 331.53 6352.09 - 4020.92 7517.77 327.67 1.59 13527.93 9570.24 18.25 1 330.42 6377.46 - 4035.00 7546.74 327.68 0.73 13622.67 9660.06 18.87 1 331.31 6403.80 - 4049.68 7576.84 327.69 0.65 1, 13683.02 9717.27 18.21 330.76 6420.59 - 4058.97 7596.00 1327.70 1.09 13778.97 9808.75 16.92 330.83 6445.86 - 4073.10 7624.91 327.71 1.34 13873.78 9899.44 16.96 331.37 6470.05 - 4086.45 7652.49 327.72 0.04 13966.55 9988.24 16.69 331.53 6493.63 - 4099.28 7679.28 327.74 0.29 14063.01 10080.67 16.58 331.11 6517.86 - 4112.53 7706.84 327.75 4 0.11 14156.61 10170.37 16.59 330.93 6541.23 - 4125.48 7733.52 327.76 0.01 I 14207.00 10218.66 1 16.59 330.93 6553.81 - 4132.47 7747.89 327.77 0.00 I 2- 30B /ME -01 20 I ' Schlumberger Well Path Plots Ma • View I 7747.88 I North - South (ft) ' - 7747.88 7747 West - East (ft) 7747.88 Cross Section View 35.10 TVD (ft) 1 10218.66 = - 7747.88 Departure (ft) Plane = 327.8 - 147.8DEG) 7747.88 2- 30B /ME -01 21 Schlumberger I Pressure Depth Plot FORMATION (AQAP psia) <>MUD A FTER (AQAP psis) 1:593 DRAWDOWN MOBILITY GRMA (gapi) 4500 5000 4500 6500 tvd (ft) E 0 200 _ Dry Test 0.01 1000 -at 9760 i 9770 9780 _ 9790 ,llill 9800 . 9810 T ' I '' 33 9820 'iE'••• 33 ❑ 9830 � , � 3? 31 0.405 psi /ft (Water) 31 9840 ❑ I i9 9850 r I 9860 T. 4. 11 $ 9870 D • 28 4 15 • 7 9880 E B T. I 9890 9900 - iiF° 9910 . I 9920 .� 9930 �- 9940 I I I 24 9950 U • ❑ ] la 9960 ❑ . t 9970 ❑ C- I 9 QQRn ❑ 1 8 = 0.795 psi /ft El u AL :i 10000 D• I 15 5 D 10010 - 14 4 10020 C 111111�= 10030 I 0.451 psi /ft (Water) 10040 pi 10050 S ol ❑ o - ;j 10060 6- 11111111 I 10070 C ] 10080 10090 L. I •IIE/ 6 /► 10100 LJ J 10110 • 5 • 5 10120 D rr I 4 41 4 10130 C 10140 3 • 3 El I 10150 10160 li _ 10170 10180 I 10190 10200 10210 10220 We I D 2- 30B/ME -01 22 I I Schlumberger Time and Date vs MD I TIME VS DEPTH 1:490 FORMATION (AQAP GRMA (gapi) 07- Mar -2009 00:00:00 09- Mar -2009 00:00:00 and (ft) ( } 0 200 4_ 500 5000 I —Dry Test 13770 Li- I 13780 13790 _____ 33 33 -- 13800 r ll 1 Q 32 1 r I Q 31 13810 31 30 13820 30 29 29 13830 fll► 13840 • 28 • 2' '1 i1 r Al 1 26 „'. , - 13850 ip I 13860 13870 1 13880 I 13890 I 13900 I 13910 13920 f Ir. l 24 13930 • 2' i l 22 23 13940 = 2 ill I -- i I�i;i 2Q1 - - - -- 13950 41' 119 13960 : 1 I . ,1$ 13970 All 7 1' 6 13980 11111 I 13990 ® - � ___ ID 14000 ,C_. I I � 14010 14020 ' I 14030 I 6 11 13 i 4 '116112 14040 1 - -- AP 9 - - -- 14050 I ir l i 1 I 14060 I 14070 I C I 14080 • 41 6 1 . I I 1'. —�— 14090 RIO i i 14100 0 ; i 4 14110 4 ' � I 14120 4 11 3 14130 • 3 I 14140 L__ - I 2- 30B /ME -01 23 Schlumberger XY MUD Before vs MUD After I 6100.00 I I •• 3 I •4 .7 II 11 •1- 8 I Mud • III Pressure , After (psia) •26 I • �4 I I I I 5600.00 5600.00 Mud Pressure Before (psia) 6100.00 I I I I I 2- 30B /ME -01 24 I UM OM — NM — MN NM • r — MI — NM — NM • Ir MI MI Pressure Vs Time Plot : Test #1 Run 2 13805.41 ft (MD) 9834.04 ft (TVD) Schlumberger 2- 30B /ME -01 I N O N N r N N N CO of OJ a o v u 0 m LL 0 - .a w 3 ) a o Q 0 0 0 U < Q LU O w N I Q 1/ 8 S W W O 0 j a c, q . LL N F , 7 W W N ■ W a w Ce W g J W 0, J W > V _, a r (0 Z 0 J U J Q 0 w ▪ Q 0 , a w 0 F a • Q 0 z 3 m LL a • LL o A el M C) C 70 O CO CO O Q 7 V O O 230 240 250 260 270 280 290 300 310 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe V Drawdown Start Invest. Gauge AQAP A Buildup Start Invest Formation Pressure 4683.88 psia • End Buildup Invest Last Read (Invest) 4683.97 psia Last Read (Final) 4683.83 psia Drawdown Start Q Drawdown Mobility (Invest) 10.106 md/cp 0 Buildup Start Drawdown Mobility (Final) 9.006 md/cp • End Buildup Mud Pressure Before 5847.38 psia Mud Pressure After 5836.67 psia • Mud After Temperature Before /After 143.82 DEGF / 143.58 DEGF Pretest Rate/Volume 1 c3 /s / 7.53 cc 60s Slope (Final) 0.06 psia /m Pressure Variance (Final) 0.56 psia 25 ■ Pressure Vs Time Plot : Test #1 Run 2 13805.41 ft (MD) 9834.04 ft (TVD) Schiumberger 2- 30B /ME -01 i Investigation i i Final i CL El_ 4 t a. w m m Q F a ( U Q Q '.. C7 W I Q J Q W W 0 D j E a w , I-- a ti w a la cr w 2 a N Cr o 1 W V) 1- • a a a 1- t ° W Z H JO Q • < 0 3 Z • 3 LL < a LL O N ' O O N \ ON K 100 200 300 400 4684.13 Detail Pressure Plot Final Time (sec) Tool Type FPWD675 MP I I I Mud Before Test Type Type 2 - C Packer TST675 Probe 4683.93 � 1 Drawdown Start Invest. Gauge AQAP m Buildup Start Invest Formation Pressure 4683.88 psia 04683.73 al End Buildup Invest Last Read (Invest) 4683.97 psia I' V Drawdown Start Last Read (Final) 4683.83 psia Drawdown Mobility (Invest) 10.106 md/cp 24683.53 l I I I I I fil, i A Buildup Start Drawdown Mobility (Final) 9.006 md/cp + End Buildu Mud Pressure Before 5847.38 psia a ■ I III I 11111 III I III 1 I! I I I , II .1 Illi I d � 111 II III ( Mud After p Mud Pressure After 5836.67 psia 4683.33 I l I I I li 1 II I IIII�II VIII III � X16 ! I��II ( +!I Temperature Before /After 143.82 7.53 / 143.58 DEGF i t ` Pretest RateNolume 1 c3 /s / 7.53 cc 4683.13 60s Slope (Final) 0.06 psia /m 233.19 268.95 304.71 340.48 376.24 412 Pressure Variance (Final) 0.56 psia Time (sec) 26 MI MI M. IIIIII M I♦ en NM 111. MII MI I= N NM EN MI MN • NM Flow Regime Identification Plot : Test #1 Run 2 13805.41 ft (MD) 9834.04 ft (TVD) (Final) Schlumberger 1e +04 2- 30B /ME -01 888 Spherical Time Function Plot : - 0 Spherical Derivative — -' -- -- ' ' ❑ Radial Derivative _ 40 i 1e +0:, I Ii.;: a 1 e +0 s i a co n O !k m cn o_ 1e +01 y ,, 11 '0 lim to +OC .Z L': 1e -01 1e +00 1e +01 1e +02 Delta -Time (sec) Slope on Spherical -0.022 4138 3 6 n p Slope on Radial -0.475 2.000 Spherical Time, 1 /sqrt(sec) Last Buildup Pressure : 4683.83 psia Extrapolated Pressure : 4683.88 psia Buildup Mobility : 12.06 and /cp Spherical Slope : -9.1 27 Pressure Vs Time Plot : Test #2 Run 2 13848.78 ft (MD) 9875.53 ft (TVD) Schlumberger 2- 30B /ME -01 1 N O NO (V tD — . cD a, a, D) O V V V - - - - -- - - - - - - - - - - - - a a - a It 0 m 1,..-:' „ � D Te d Ui I ., m 0 a •r n a ft &- a a 0 a 0 U C cn d 0 IL . 0 J S' W W 0 w p. a c LL a w M w tY 1! a J i- W U J ,, > 0 - - D i I- <: < a 0) Z J W - f 0 a a f� cr N � ! = d (� N U ! 1- Q u P i Q u Z Co d 0 Z LL Q LL 1 N CD <D CO OV 0 i h A N o N 7- NO 250 260 270 280 290 300 310 320 330 340 350 360 370 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Q Drawdown Start Invest. Packer TST675 Probe Gauge AQAP A Buildup Start Invest Formation Pressure 4749.93 psia • End Buildup Invest Last Read (Invest) 4751.19 psia 0 Drawdown Start Last Read (Final) 4749.93 psia 0 Buildup Start Drawdown Mobility (Invest) 1.072 md/cp Drawdown Mobility (Final) 1.318 md/cp • End Buildup Mud Pressure Before 5766.93 psia Mud After Mud Pressure After 5766.46 psia Temperature Before /After 144.97 DEGF / 144.82 DEGF Pretest Rate/Volume 0.64 c3 /s / 2.45 cc 60s Slope (Final) -.12 psia /m Pressure Variance (Final) 0.5 psia 28 • • • • • I• • I• r • • I• N — • • M i• Mi' MO MN MN — Me — I♦ MN — — II MI MI — MI — • NM IIIIII Pressure Vs Time Plot : Test #2 Run 2 13848.78 ft (MD) 9875.53 ft (TVD) Schlumberger 2- 30B/ME -01 I Investigation I Final I°OP- U' _.. ..._._ n W m m 0 n - o. R a a m a U Li; Q wI Q J K W W a W W N w a W c, W 2 J a 0 a J i2 W W J / O> U _, d 7 / W Z 7 -' U 1 W s I- p a W Q 0 a C! E tn o F a J a 0 3 A D z 3 (0 LL z a — \ LO / m a'. a' / ai o a a o rn rnO rn 100 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type FPWD675 Test Ty 4750.23 ( '� II t l I I I II1II I Ell h I � 1!1 g1111 t I V Drawdown Start Invest. Packer pe TST675 Probe 1 4750.03'MINII . I I Gauge AQAP I I Buildup Start Invest Formation Pressure 4749.93 psia 3 y End Buildup '8 4749.83'_,I��I1I II I II I .� I ' I I I 1! I I �) Invest (Invest) p L Read Invest 4751.19 psia 1 I 1 I Drawdown Start Last Read (Final) 4749.93 psia ' 11 I, 0 Drawdown Mobility (Invest) 1.072 md/cp oa'i4749.63 ( i � I A Buildup Start Drawdown Mobility (Final) 1.318 md/cp � II � II i 1 . I I Mud After Mud Pressure Before 5766.93 psia a Mud Pressure After 5766.46 psia 4749.43 Temperature Before /After 144.97 DEGF / 144.82 DEGF ` J II Pre test RateNoume 0.64 c3 /s / 2.45 cc 4749.23 ��� it 11 1 I I I II' �i ILI I I I 60s Slope (Final) 12 psia /m 259.69 289.75 319.81 349.88 379.94 410 Pressure Variance (Final) 0.5 psia Time (sec) 29 Flow Regime Identification Plot : Test #2 Run 2 13848.78 ft (MD) 9875.53 ft (TVD) (Final) Schlumberger e +oa 2- 30B/ME -01 O Sphencal Derivative O Radial Derivative 11, \ \ \\ / ,, 8 ,`�\ to +0 lll.���� \` l j1 tl llllllllllllli tii.: /I ■ -t. • • 'ra 0 ii. 1 a) Tjt a) Co • �4 > .'cl I;___ . p 1 e +02 . _ to ♦ N d • 0 • II r J 1e +01 _ - I I _,_ 21 U D 0 1 e +OG 1e +00 1e +01 1e +02 Delta -Time (sec) 30 • — — — — • — • — i • • — — — — • • NM NM NM MI I NM OM NM MOI NM IIM • • INIS — MN Me MN Pressure Vs Time Plot : Test #3 Run 2 14131.78 ft (MD) 10146.58 ft (TVD) Schiumberger 2- 30B/ME -01 I O N OO O O O O N '' N N a LL n W m m ❑ n V3 Ft - • w ? Ni a -8 U w w a u) ❑ a , , , a w ~ 0 f' U w cn K w i 2 w a 0 Cr ' j ❑ w N O > 0 - - 0 F < a a ti Z 0 -' U W w o F - ' a W Q ❑ a E a r a co a a 0 z 3 N U a u_ I ' O 0 0 0 O O O O N N 0 N 7 N N 200 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe V Drawdown Start Invest. Gauge AQAP 0 Buildup Start Invest Formation Pressure 4705.52 psia • End Buildup Invest Last Read (Invest) 3973.69 psia Last Read (Final) 4705.52 psia X Drawdown Start Drawdown Mobility (Invest) 0.667 md/cp Buildup Start Drawdown Mobility (Final) 0.094 md/cp • End Buildup Mud Pressure Before 6004.11 psia Mud Pressure After 6004.67 psia • Mud After Temperature Before /After 149.76 DEGF / 149.56 DEGF Pretest Rate/Volume 0.42 c3 /s / 0.52 cc 60s Slope (Final) 0.11 psia /m Pressure Variance (Final) 0.78 psia 31 Pressure Vs Time Plot : Test #3 Run 2 14131.78 ft (MD) 10146.58 ft (TVD) Schlumber 2- 30B /ME -01 ger Invstigal Final � — a, c n N. N- ik . . . '.\''‘ . - ''. W m O a n M a a 2 Q U tL NI O (— S ' W P c D = a F d 7 w a g w w __ o - -- _ - = d N d - • a U O U ~ ce • a Q d U ~ a U 0 a • d CO O r Q a o o z a v' LL a LL Lo m o CD of o ai ai o m '. rn0m 100 200 300 400 4735.52 Detail Pressure Plot (Final) Time (sec) Tool Type FPWD675 . Mud Before Test Type Type 2 - C Packer TST675 Probe 4715.52 Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4705.52 psia L ast Read (Invest) End Buildup Invest ( ) 3973.69 psia Last Read (Final) 4705.52 psia `J �i 0 Drawdown Start Drawdown Mobility (Invest) 0.667 md/cp 4675.52 A Buildup Start Drawdown Mobility (Final) 0.094 md/cp 2 IN End Buildup Mud Pressure Before 6004.11 psia Q_ r, Mud Pressure After 6004.67 psia 4655.52 Co • Mud After Temperature Before /After 149.76 DEGF / 149.56 DEGF Pretest RateNolume 0.42 c3 /s / 0.52 cc •• 60s Slope (Final) 0.11 psia/m 4635.52 P ( ) P 140.25 194.4 248.55 302.7 356.85 411 Pressure Variance (Final) 0.78 psia Time (sec) 32 IIII NM — — — — MI — MI — — UM MB • i MN — MI 1 Mile Ma — — NM NM — OM NM • • I NM — S 1111110 IIIIII ION 1111110 Flow Regime Identification Plot : Test #3 Run 2 14131.78 ft (MD) 10146.58 ft (TVD) (Final) Schlumberger 1e +o 2- 30B /ME -01 _ O Spherical Derivative 5.•.., • 0 Radial Derivative = = —■■ ♦ ♦`\` %%S -% Emma — =MBE g M ■■111 III S •♦ • 1e +Oq • ... O 4 1 • - -_ co •• ❑ • ,.. a, et i isai a _ ♦1 ti to co r _41 ❑ co r., 1 e +OS • • . y • —ii ti 4r �.• a 1 e +0c le +00 1e +01 1 +02 Delta -Time (sec) 33 Pressure Vs Time Plot : Test #4 Run 2 14113.67 ft (MD) 10129.22 ft (TVD) Schlumber er 2- 30B/ME -01 9 1 O s o s O - Oo O , LL o. w m m 0 N a Q co < O a �7 0 < a Cr 2 < _ ^w 0000 0 0 0 0 0 0 0 0 0 c 0 0 0 O 0 0 O © O o O 4 D O O 0 O O• o N W W w F a Q.- a � it w 0 a 2 U a O> U - K 7 1— < < a I- 0 Co Z I-- , Q I- 0 a LIJ Q O O a 0' o F a a 0 z 3 N LL E Q LL O <h O O O O N O O N N O N O R O V 210 220 230 240 250 260 270 280 290 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe X Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4687.98 psia • End Buildup Invest Last Read (Invest) 4688.21 psia X Drawdown Start Last Read (Final) 4687.98 psia Q Drawdown Mobility (Invest) 59.016 and /cp Buildup Start Drawdown Mobility (Final) 63.305 and /cp • End Buildup Mud Pressure Before 5992.19 psia Mud Pressure After 5993.41 psia Mud After Temperature Before /After 147.76 DEGF / 147.67 DEGF Pretest RateNolume 1 c3 /s / 7.36 cc 60s Slope (Final) - 2.72E -03 psia /m Pressure Variance (Final) 0.21 psia 34 • MI — — MI MI — — MI • — — — — — — MI ill MIN NM OM i i M MB — — — I NM • -- — On MI • Pressure Vs Time Plot : Test #4 Run 2 14113.67 ft (MD) 10129.22 ft (TVD) Schiumberger 2- 30B/ME -01 Investigation It Final O o so o o — o O L i 0 0 0 m LL o. 0 m a y a .. • a M a a a o Q Ui O L;, a w w > N D a Cr a U) H D LL 2 w I I: � cr w g a D a: N a w I- (0 Z_ 0 J Q H U O U' w ,,,< < 0 0 Iii_ m 07 F 0 z' cn u- z Q LL — ^r V V O o M / \ O o O O / \ O O O O Q '- Q Q 100 — 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type FPWD675 4688.28 Test Type Type 2 - C � I' • Mud Before �'� ��I IIl Probe 4688.08 i um I i r r , i s 11 Ph�i � , �i� ,El ! � �, ,� q I �t� „ �' �Rn� l Invest. ���� � r ' R� �� t i iR� iii R i 111 l r� O Buildup Start Invest Gauge AQAP Formation Pressure 4687.98 psia N p End Buildup Invest Last Read (Invest) 4688.21 psia Q4687.88 Last Read (Final) 4687.98 psia j Dr awdown Start 02 0 Drawdown Mobility (Invest) 59.016 and /cp 24687.68 Ir [ 0 Buildup Start Drawdown Mobility (Final) 63.305 and /cp End Buildup Mud Pressure Before 5992.19 psia a I �IJ I ` ��� �I I IY ` � �� ■`y � b�I�l�li ` Mud Pressure After 5993.41 psia 4687.48 J' I + l ill `�! . h iJ IIIW� IWI�� . I YW IJ ill AIM ii • M Mud After Temperature Before /After 147.76 DEGF / 147.67 DEGF of dialimillommoliiiiii Pretest Rate/Volume 1 c3 /s / 7.36 cc 60s Slope (Final) - 2.72E -03 psia/m 4687.28 211.63 251.3 290.98 330.65 370.33 Pressure Variance (Final) 0.21 psia Time (sec) 35 Flow Regime Identification Plot : Test #4 Run 2 14113.67 ft (MD) 10129.22 ft (TVD) (Final) Schlumberger 2- 30B /ME -01 1e +0? I -! Spherical Derivative -- - -- - - - - -- 0 Radial Derivative — - 1e +0q 1e +01 > I I -_ ID El? 1 1 1 ! 1 to a. 1e +OC 4. le -01 ::ai le -02 1e +00 1e +01 1e +02 Delta -Time (sec) 36 OM • V • OM • • • • • — — MI • MI IMO MIN MI NM I UM • (♦ IIMI IMI MI MI I MI MI 1111. MI NM MIN — Pressure Vs Time Plot : Test #5 Run 2 14101.73 ft (MD) 10117.78 ft (TVD) Schlumberger 2- 30B /ME -01 1 O O O O o � o0 0 m ao co o a a LL O 0 S a O n o m Q Cal Q —V - - W '' N v _ - W > U D W a rr d L C 1 W U w a w Ui w 2 J d D CC n a - • ,2 W U1 - O F r W a I- a a a I- W Z F J Q O 0 U) ,_ < 0 0 a cn 0 F • Q p - - Z 5 c Z a Q LL 0 m i' 0 0 0 O N o O O a 4'04' 210 220 230 240 250 260 270 280 290 300 310 320 330 340 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe 0 Drawdown Start Invest. Gauge AQAP A Buildup Start Invest Formation Pressure 4683.75 psia End Buildup Invest Last Read (Invest) 4683.22 psia III Last Read (Final) 4683.75 psia Q Drawdown Start Drawdown Mobility (Invest) 43.154 md/cp A Buildup Start Drawdown Mobility (Final) 36.033 md/cp Mud Pressure Before 5984.23 psia El End Buildup Mud Pressure After 5983.56 psia • Mud After Temperature Before /After 146.86 DEGF / 146.86 DEGF Pretest Rate/Volume 0.99 c3 /s / 7.33 cc 60s Slope (Final) 0.1 psia /m Pressure Variance (Final) 0.37 psia 37 Pressure Vs Time Plot : Test #5 Run 2 14101.73 ft (MD) 10117.78 ft (TVD) Schlumberger 2- 30B/ME -01 Investigation I Final O o oQ o o - o 0 0 0 0 W LL ._ 0 .. ... .. ..._._ .. ._. _.. cn c O a i o < d a ai d W 1 a - W W O N D - IY a w < a. w a w Ce w 2 _ a D o: D a 2 N a O U r- a a ¢ a w Z o a l r w ▪ , a W O ff - < 0 V V .... a a N LL - _. - ___ LL O c7 / ■ O N 7 g N O M 1 00 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type Ype FPW D675 I� ���' �,� 1 ��I • Mud Before Ee"675 Probe 4683.85 D raw d own Start Invest. o INE11111111111111111111% 1 '�' T I Formation Pressure 4683 11 � I B u il dup dup In est 2 psis 2 04683.65 If End B uildup Invest Last Read (Invest) 4683.22 psis tf l I 1 r1 2 h 11 1� Il �I� � p ! .,� I�'. iiil � ii1 - 'III - II! !i l I ' 0 Drawdown Start Last Read (Final) 4683.75 psia Drawdown Mobility (Invest) 43.154 md/cp 4683.45 0 Buildup Start Drawdown Mobility (Final) 36.033 md/cp a 1 II End Buildup Mud Pressure Before 5984.23 psia Mud Pressure After 5983.56 psia � sa 4683.25 III IN Mud After Temperature Before /After 146.86 DEGF / 146.86 DEGF Pretest RateNolume 0.99 c3 /s / 7.33 cc 4683.05 1 I 11 , HI ,I I 11 11 1 I 60s Slope (Final) 0.1 psia /m 211.5 251.2 290.9 330.6 370.3 410 Pressure Variance (Final) 0.37 psia Time (sec) 38 MN MO MI MI OM • • NM I• II= • MI — NM NM I= MN IM • NI NM OM MB NM MO IIIIII MI MN • = • MI NM Flow Regime Identification Plot : Test #5 Run 2 14101.73 ft (MD) 10117.78 ft (TVD) (Final) Schlumberger 1e +04 2- 30B/ME -01 t Q Spherical Derivative -; - ; a— ❑ Radial Derivative I 1e +02 1e +02 U, N > > p 1e +01 i N N F . 1 e +OC , . 9 , e 0 ME ■■M 11111,: -_ t= a 0 k■iff j :;11 4 4°. ''' IS 1e -01 /r_ xir _ . , ' ►�� ta III t _. to -02 1e +00 1e +01 1e +02 Delta -Time (sec) 39 Pressure Vs Time Plot : Test #6 Run 2 14086.13 ft (MD) 10102.83 ft (TVD) Schlumber er 2- 30B/ME -01 9 0 0 8 o - 0 0 � a ........................ . 5 0 v L 0 90000®000000 0 0 0 0 c o 0 0 0 0 0 0 0 0 0 C 0 -O 0 0 0 0 0- 0 0 0 0 0 . a w m m V! ❑ : . a c aQ a U' 2 U w Q w O o D 2 w Cl- 2 a g Ill E w co LL a J I a 0 i t m a J W > � W O ¢ ' a a r 2 Z1,2 - 0 W 0 JO 0 w < 0 0 a y O F 3 a 0 0 0 Z N LL LL \ \ 4 0 o 0 0 o in o 0 0 ° a C 40 4 210 220 230 240 250 260 270 280 290 300 310 320 330 340 350 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C X Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4676.49 psia • End Buildup Invest Last Read (Invest) 4677.21 psia V Drawdown Start Last Read (Final) 4676.49 psia Drawdown A Buildup Start Drawdown Mobility (Invest) 22.583 and /c Y( ) P End Buildup Mud Pressure Before 5987.15 psia Mud Pressure After 5982.59 psia Mud After Temperature Before /After 146.32 DEGF / 146.39 DEGF Pretest RateNolume 0.99 c3 /s / 7.33 cc 60s Slope (Final) 0.04 psia /m Pressure Variance (Final) 0.3 psia 40 MN 1111.1 IIIIII • — I NM MI MN • MI N MII 11111 = • MI 111011 liM MI IIIM MIN IMINI 11111. N UM IIIIII IIIIII MB • MI • MI Pressure Vs Time Plot : Test #6 Run 2 14086.13 ft (MD) 10102.83 ft (TVD) Schlumberger 2- 30B /ME -01 Investigation I I Final 8 8 80 8 0 0 0 h r r 1 A LL a W m m y F U a 0 ' 2 0 J r n a O W r y D . a w 2 w a w ce w • J j d u) Cr 8 j W wE J .. w d • ¢ Q - F a ▪ Z 7 J O U W a o 0 W (7 F < a Co 0 . O d � <i 0 > cl Z m U. • a • LL 0 O N NO N 1 00 200 300 400 Detail Pressure Plot (Final) Time (sec) Tool Type FPWD675 4679.49 o • Mud Before T est Type Type 2 C YP YP Packer TST675 Probe Drawdown Start Invest. 4678.49 Gauge AQAP Buildup Start Invest Formation Pressure 4676.49 psia m III End Buildup Invest Last Read (Invest) 4677.21 psia 04677.49 1111111 oi 'lorry 1IIR1 11R1ir"' Arm1g111rj1R"' tnw*PIRirmrirrir11'!nrplAIIII1 Drawdown Start Last Read (Final) 4676.49 psia 0 Drawdown Mobility (Invest) 26.324 and /cp e A Buildup Start Drawdown Mobility inal 22.583 md/cp I. '' �.. tll) Iir���u1. �11Y�Ji�lill, ru; �l. itialLd.{ �.) J. �u1l. i�iu�� , u li �� Ill ii� , J�I � I� , ��J �.�� 1 NIL/ Y( ) P ■ 2 V U End Buildup Mud Pressure Before 5987.15 psia a Mud Pressure After 5982.59 psia 4675.49 Mud After Temperature Before /After 146.32 DEGF / 146.39 DEGF Pretest Rate/Volume 0.99 c3 /s / 7.33 cc 60s Slope (Final) 0.04 psia /m 4674.49 Pressure Variance (Final) 0.3 psia 215.06 254.25 293.44 332.63 371.81 411 Time (sec) 41 Flow Regime Identification Plot : Test #6 Run 2 14086.13 ft (MD) 10102.83 ft (TVD) (Final) Schiumberger 1e +f , 2- 30B /ME -01 • Spherical Derivative 0 Radial Derivative 1e +0 I I to a) Co CT) 1e +01 C u) a) d •1• 1 e +OG a 1 1 . P yam_ g__ iii 0 1e -Ot. �A le 1e +00 1e +01 le +02 Delta -Time (sec) 42 MN I• MN M — — — ME M — — — — OM — E OM OM NM MN NM MI MI I MN MI 111111 111.1 UM NM NM Pressure Vs Time Plot : Test #7 Run 2 14052.13 ft (MD) 10070.24 ft (TVD) Schiumberger 2- 30B /ME -01 J 8 8 808 o - o o to to m Tr Tr I W LL 9 W m to Q N d m < I 0 S 0 Q W u '1 a J a . W W • 7 0! W a . N a QQ I- L 00000000000 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 O 0 0 0 0 0 w W w W w 0 ll� W 0 W o a J • W W o aQ aF U) Z 7 U W Q H , Q w - a o a a C a i- a - • < 00 - 3 3 ( LL z a Q LL O M O O O O tf) O 0 O V .:-- V O V 200 210 220 230 240 250 260 270 280 290 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4660.82 psia • End Buildup Invest Last Read (Invest) 4660.36 psia Drawdown Start Last Read (Final) 4660.82 psia Drawdown Mobility (Invest) 98.738 md/cp Buildup Start Drawdown Mobility (Final) 132.879 md/cp NI End Buildup Mud Pressure Before 5957.09 psia Mud Pressure After 5955.62 psia IN Mud After Temperature Before /After 146.14 DEGF / 146.16 DEGF Pretest RateNolume 1 c3 /s / 7.53 cc 60s Slope (Final) 0.02 psia /m Pressure Variance (Final) 0.13 psia 43 Pressure Vs Time Plot : Test #7 Run 2 14052.13 ft (MD) 10070.24 ft (TVD) Schlumber 2- 30B/ME -01 ger Investigation II Final o o oQ o o ,n o o N.. o 0 N. N LL n W m O 0 w a U Q O d r W I a >O N m i t w I- rn 1- a 7 w a w w co O > U _, 0 7 F a a a U w Z r- o 1- g a . a D 0 a O F a co - a 0 3 z 3 a_ LL Z a a a _ j I O M 0 0 0 o N_ O N 7 NO N 100 200 300 400 4661.12 Detail Pressure Plot Final Time (sec) Tool Type FPWD675 .1.1 ■ Mud Before Test Packer Type 2 - C I I x Drawdown Start Invest. Packer TST675 Probe 4660.92 Gauge AQAP ' �����1� Buildup Start Invest Formation Pressure 4660.82 psia n4660.72 ,' II End Buildup Invest Last Read (Invest) 4660.36 psia 1 I II I f i i I ; ,- TI n I - 9 1 111' r' 1 9' ,i pr, r . 1 , - . f i 1 • t 0 Drawdown Start Last Read (Final) 4660.82 psia Drawdown Mobility (Invest) 98.738 md/cp 4660.52 0 Buildup Start Drawdown Mobility (Final) 132.879 md/cp Li J ` i iii i i ii�� i i� I. �� l : Buildup Mud Pressure Before 5957.09 psia a Mud Pressure After 5955.62 psia 4660.32 � � Mud A fter After Before /After 146.14 / 146.16 DEGF Pretest retest RateNolume 1 c3/s c3 /s / 7.53 7.53 cc 4660.12 ,� 60s Slope (Final) 0.02 psia /m 205.56 246.45 287.34 328.23 369.11 410 Pressure Variance (Final) 0.13 psia Time (sec) 44 • • IIIIII MI NM NM MN MIIIN NM N MI MI 1111111 N N 111111 MN N • I= MN • IIIIIII NM • • I • = MN • • NM Flow Regime Identification Plot : Test #7 Run 2 14052.13 ft (MD) 10070.24 ft (TVD) (Final) Schlumberger 1e +0 - 2- 30B /ME -01 -1 0 Spherical Derivative - -+ ❑ Radial Denvative • 1e +0's 0 0 0 /I S . IUII1II f co 1e +01 ___ao j " w il > =M — I . O 1 t t 4. • M� - O s • �'s�,•••• +∎ * * 1tt'i7 ■ ■11 d co 1e +OC O IliSi i 4 �% iralpi ka: a- ii pq V = I 80 a:ri G n 1 e -01 u it 1 elf! + II III u IN u 4. a 1 ,.-1 II .„ •i 1e -02 1e +00 1e +01 le+02 Delta -Time (sec) 45 Pressure Vs Time Plot : Test #8 Run 2 14048.76 ft (MD) 10067.01 ft (TVD) Schlumber er 2- 30B /ME -01 9 o O 0 0 o N O O N � c0 W V O V 11 11 11 11 LL 11 t0 W m N 11 a n 0- '1 a ¢ O a 11 < O ¢ U ¢ NI PC 11 W 0 W W CI) 0 Y 11 a W ~ a ' (0 W a U rr w a 7 Cr N a- - ¢ uj I o 7 W W o - a U W Z ¢ ¢ 3 O a cn 0 a ¢ o o Z 3 y LL Z ¢ LL 0 0 0 0', 0 0 0 P/ 0ao 300 400 Time (sec) Tool Type FPWD675 Mud Before Test Type Type 2 - C Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4660.94 psia • End Buildup Invest Last Read (Invest) 4661.44 psia Q Drawdown Start Last Read (Final) 4660.94 psia Drawdown Mobility (Invest) 7.035 md/cp A Buildup Start Drawdown Mobility (Final) 6.246 md/cp II End Buildup Mud Pressure Before 5951.62 psia II Mud Pressure After 5951.15 psia Mud After Temperature Before /After 145.69 DEGF / 145.83 DEGF Pretest RateNolume 1 c3 /s / 7.31 cc 60s Slope (Final) 0.05 psia /m Pressure Variance (Final) 1.31 psia 46 • i ! V MN — — — — — • — • • NM MI • R ONNIIIMINIIIIIMIIIIIIIIMIIIIMMIll• 11111M MITI — — M — — — I E Pressure Vs Time Plot : Test #8 Run 2 14048.76 ft (MD) 10067.01 ft (TVD) Schlumberger 2- 30B /ME -01 Investigation I I Final 8 88 i °008 A r On ■ t W LL a W m a ❑ a a n n ci ¢ 0 2 ¢ o ¢ w w o W g3 Lu o o a rt ,-- a rn 1— 7 W W Lu cn LL a w w 2 J a 7 a w o < - a j �� . < j ' U ' I ii J ¢ 0 w a 0 ❑ U' LL a °w o ' St_ d F ¢ CO D ¢ 0 0 0 Z 3 co LL A z a ¢ LL ■ / 0 O ' N N O N N O N /" 100 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type FPWD675 4661.24 lir I I I I Test Type T e 2- C Mud Before S T675 Probe Packer TS Drawdown Start Invest. 4661.04 Gauge AQAP • Buildup Start Invest Formation Pressure 4660.93 psia 24660 L ast ReadInvest .84 / End Buildup Invest (Invest) 4661.44 psia 7 . ' Last Read Mobility 4660.94 psia l) Drawdown Mobility (Invest) 7.035 md/cp 24660.64 4660.64 0 B ui ld u Drawdown p Start Start Drawdown Mobility (Final) 6.246 md/cp 2 .I I End Buildup Mud Pressure Before 5951.62 psia d Mud Pressure After 5951.15 psia 4660.44 + 1i I U M ud After Temperature Before /After 145.69 DEGF / 145.83 DEGF J Pretest RateNolume 1 c3 /s / 7.31 cc ii I O 1 II ■ vii 60s Slope (Final) 0.05 psia /m 4660.24 Pressure Variance (Final) 1.31 psia 255.75 293.2 330.65 368.1 405.55 443 Time (sec) 47 Flow Regime Identification Plot : Test #8 Run 2 14048.76 ft (MD) 10067.01 ft (TVD) (Final) Schlumberger 1e + � 2- 30B /ME -01 Spherical Time Function Plot : __ 1 — Spherical Derivative ' -- _ _ _ '— 6000 _ O Radial Derivative t -- '- 1e +0::, I I I "Ii ii_ -I, 111111 - 11111■ ■I � • 1 e +02 _ I 1 * . CO � i � ■ ■■�� _ =• ■ ■■ CD =nom a) • I n� ■ .•iui 000 ° . !� , MI NMI D 1 D •`'. u) M ■' �Ai r ` - 1 nrr i• •III I I ,'� P to I r r l ` ,�' `��. ter I� � rrJ L U • ` � oc I ; • • c; ,le r��llii 1e -01 1e +00 1e +01 1e +02 Delta -Time (sec) Slope on Spherical 0.008 3873 n ( ) Slope on Radial -0.457 3.6 2.000 0 Spherical Time, 1/sqrt(sec) Last Buildup Pressure : 4660.94 psia Extrapolated Pressure : 4660.93 psia Buildup Mobility : 18.16 rnd /cp Spherical Slope : -4.9 48 MI • • N • — — MIIII • I• • MI MI • • = • MI On MI I= =I MI 1111111 • MI NM 11111. IIIIIII MI MI MI MI Pressure Vs Time Plot : Test #9 Run 2 14046.03 ft (MD) 10064.39 ft (TVD) Schlumberger 2- 30B/ME -01 o o 3 08 O N O O co — N � ✓ V V N LL 0 ' W m m a ? n ci < • 0 Q () Q u)1 0 a W O U) 0 a K a W W w a w D00000 w 000000000000 0 0 0 0 0 0 O 0 9 0 8 0 0 0 0 0 0 0 0 0 f 2 a CC (n a - W N J W o ) a a a F v z a W a o o a d r Q en a 0 5 0 N LL Z¢' a LL f"J O O O O O 0 0 A := N O O � V V 300 Time (sec) Tool Type FPWD675 ▪ Mud Before Test Type Type 2 - C Packer TST675 Probe v Drawdown Start Invest. Gauge AQAP A Buildup Start Invest Formation Pressure 4657.37 psia • End Buildup Invest Last Read (Invest) 4657.43 psia Last Read (Final) 4657.37 psia Drawdown Start ✓ Drawdown Mobility (Invest) 132.73 and /cp A Buildup Start Drawdown Mobility (Final) 149.237 and /cp ▪ End Buildup Mud Pressure Before 5947.1 psia Mud Pressure After 5945.27 psia ▪ Mud After Temperature Before /After 145.54 DEGF / 145.6 DEGF Pretest Rate/Volume 1 c3 /s / 7.35 cc 60s Slope (Final) - 1.23E -03 psia /m Pressure Variance (Final) 0.16 psia 49 Pressure Vs Time Plot : Test #9 Run 2 14046.03 ft (MD) 10064.39 ft (TVD) Schlumber 2- 30B/ME -01 ger I Investigation II Final I 0 0 0 0 o 0 0 0 0 0 k, N. r r m u___, . F, W m m • O Q U a a N (<:15 .M.. L 1 - a w w N j Q! Z a Co 1-- d 0 w a � Z w f - a 0 a O a 2 Co a Co > 0 - Ca 0 < < a I U CO Z H 0 ¢ • 0 w a W O 7 ¢ oO Z m w Z a a L O m I / \ 0 0 0 00 o / N °v � '. °v � e° '' 100 200 300 400 500 Detail Pressure Plot Final Time (sec) Tool � " Type A I nIII � YPe FPWD675 ���� I . Mud Before Test Type Type 2 - C Packer TST675 Probe ` , Drawdown Start Invest Gauge AQAP 4657.47 I U 1i iJ` �` + j Last Read Fil thi IC �� ���il��l���l dBPi dup Investt Last Re (Invest) 4657.43 psis 24657.27 k End na 4657.37 4657.37 psia 1 1, ��I111111� X Drawdown Start (Final) psia Drawdown Mobility (Invest) 132.73 md/cp x4657.07 II- ■ Buildup Start Drawdown Mobility (Final) 149.237 md/cp End Buildup Pressure Before 5947.1 psia Mud Pressure After 5945.27 psia 4656.87 II U Mud After Temperature Before /After 145.54 DEGF / 145.6 DEGF Pretest Rate/Volume 1 c3 /s / 7.35 cc 4656.67 60s Slope (Final) - 1.23E -03 psia /m 242.56 282.25 321.94 361.63 401.31 441 Pressure Variance (Final) 0.16 psia Time (sec) 50 MI MI M MN INIO INNI MI MN MI I MI OM MB IIIIII MI MN INN MI II. NM NM IIIIIN MI MI MI IMO IIIII IIMI NM IIM 1•1111 11.1 1111. IIIM Flow Regime Identification Plot : Test #9 Run 2 14046.03 ft (MD) 10064.39 ft (TVD) (Final) Schlumberger 2- 30B/ME -01 1e +0 I • Q I Spherical _- Derivative i - -- - � - M O Radial Derivative ii4 1e +0• 1e +01 to . I a) > ti p 1 e +01 _ ,♦ ,■■ N ti �� q ,— _5 AI �.t`: le 01 �_ i I I r ♦ a r 1e -0. 4 9 _ C 1e-O 1e +00 le +01 1e+02 Delta -Time (sec) 51 Pressure Vs Time Plot : Test #10 Run 2 14042.99 ft (MD) 10061.48 ft (TVD) Schlumberger 2- 30B /ME -01 J li3 ! 000 I . iii . : t , ,: . : ' : : : : :: y U S w m m a g Q a N O Q Q Q U W Q N I Q d K L ,2 W a w 12 a D w w a w Cr w • . a Cl) a J 12 W w J O a a a p- 0 co — I- 8 Q ce a ww a a CO a; 1- 3 a 00 3 i F N 0 Q LL :♦ 0 0 0 0 0 .n M O u' o V V O 200 210 220 230 240 250 260 270 280 290 300 310 320 330 340 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C 0 Drawdown Start Invest. Packer TST675 Probe Gauge AQAP A Buildup Start Invest Formation Pressure 4657.11 psia II End Buildup Invest Last Read (Invest) 4656.97 psia V Drawdown Start Last Read (Final) 4657.11 psia Drawdown Mobility (Invest) 63.423 and /cp A Buildup Start Drawdown Mobility (Final) 49.8 and /cp • End Buildup Mud Pressure Before 5946.35 psia ll Mud Pressure After 5943.85 psia Mud After Temperature Before /After 145.08 DEGF / 145.17 DEGF Pretest RateNolume 1 c3 /s / 7.54 cc 60s Slope (Final) 0.08 psia /m Pressure Variance (Final) 0.15 psia 52 • • 11= OM • • MIN • MN IIIII MIN ONO INE • MO • • • • MI • • 1.111 IM MIII M MB 11= • MN 11= • ' MI 1111. MN INE Pressure Vs Time Plot : Test #10 Run 2 14042.99 ft (MD) 10061.48 ft (TVD) Schlumberger 2- 30B /ME -01 Investigation I[ Final 1 0 0 8 08 0 .n O 0 o: o O n r r f d14 I ll t ""4. N LL a, w m m co Q • d Q • T U Q N1 d W J S W O • co j W a 0 " w of L. a w • a 0 CC - • D W W o ▪ a a a r w < 0 o a I I- 0: 0 0 a a 0 F < Q O z (0 u- z a Q LL O O O O O / 100 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type FPWD675 :::::: ' ■ Mud Before Type 2 - C robe r Drawdown Start Invest. MIR I 1 1 I I ] ' F � �� r �l ri I II ' Buildup psia Start Invest Formation Pressure 4657.11 sia End Buildup Invest Last Read (Invest) 4656.97 psia Q4657.01 .,, • II , r I II r I I Last Read (Final) 4657.11 psia 2 V Draw Start Drawdown Mobility (Invest) 63.423 and /cp 2 � i 1I .: . 1, i . 1 , I I i ,1 i ■, . A Buildup Start Drawdown Mobility (Final) 49.8 and /cp 4656.81 ` ` ` �I I `` Mud Pressure Before 5946.35 psia d il 1 Ii t ills i 1 Iiiiii�V�VirI,II�IIII iii i llikil ili 1 ' I MI End M d Afterup Mud Pressure After 5943.85 psia 4656.61 ' I Temperature Before /After 145.08 DEGF / 145.17 DEGF II .'IIIRII Pretest RateNolume 1 c3 /s / 7.54 cc 60s Slope (Final) 0.08 psia /m 4656.41 205.5 246.4 287.3 328.2 369.1 410 Pressure Variance (Final) 0.15 psia Time (sec) 53 Flow Regime Identification Plot : Test #10 Run 2 14042.99 ft (MD) 10061.48 ft (TVD) (Final) Schlumberger t e +oa 2-30B/ME-01 Spherical Derivative 0 Radial Derivative 1e +0::: t fl 1e +02 t l I to a) _ � I m p 1e +O1 a) 1e +OG O .4 • 4,4 lit le -01 .., .11 tr. � IID 1e -02 1e +00 1e +01 1e+02 Delta -Time (sec) 54 MI • MI I IIIIII M • • • 111.11 1.1111 INO IIIIII MB NM — MIN MIN NE MN • IIIIII • 11111 MO • MB MN • ININ (♦ Pressure Vs Time Plot : Test #11 Run 2 14040.00 ft (MD) 10058.62 ft (TVD) Schlumberger 2- 30B /ME -01 I - ✓ I ',.2 a-.0 Q o o 0 co co co a v e i W LL - W m N aQ O 0 a U • 0 2 I O - LL 0 w W > Co a ce a. co H D w w Co w a w ce w ,) W W I- „ Q W Q ❑ a O a y a F a • a O < • ; a LL 1 0 210 220 230 240 250 260 270 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe V Drawdown Start Invest. Gauge AQAP A Buildup Start Invest Formation Pressure 4656.3 psia El End Buildup Invest Last Read (Invest) 4655.98 psia Last Read (Final) 4656.25 psia V Drawdown Start Drawdown Mobility (Invest) 56.244 md/cp 0 Buildup Start Drawdown Mobility (Final) 63.822 md/cp Mud Pressure Before 5935.32 psia End Buildup Mud Pressure After 5933.24 psia • Mud After Temperature Before /After 144.77 DEGF / 144.84 DEGF Pretest RateNolume 1.01 c3 /s / 7.54 cc 60s Slope (Final) 0.02 psia /m Pressure Variance (Final) 0.12 psia 55 Pressure Vs Time Plot : Test #11 Run 2 14040.00 ft (MD) 10058.62 ft (TVD) Schlumberger 2- 30B /ME -01 Investigation I I Final l 8 3 OO 3 O - O O n n n ■ f t 1 1 N F-5 ( a O a a of < 0 E < I C) < CO I ° a o Ill iY it w a w < a D w a i t Lu w m • - a ai a o D' w w w > < < a D I A A _ ... CO Z 0 0 < I- g 0 0 0 E � 3 F a • a 00 0 Z 0 N a Z LL < LL O M O O O O / / \ O N NO N 100 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type IIMPFIFFIFITRITRIVIT111,10171111Firrirrimi r Type 2 - 5 • Mud Before Test Type Type 2 C Packer TST675 Probe 4656.35 ^ I Drawdown Start Invest Gauge AQAP s 0 `1 II Jf'' 'I I f II +' + I � ,'Y Buildup Start Invest Formation Pressure 4656.3 psia n4656.15 I Al ,dl ii, 'at 'il l,� hlJllii .1.I�Illil�il��till��Ilii. Iiiiidli i�rltIII llul ioilllildli�IIW iii il, ii , Iila End Buildup Invest Last Read (Invest) 4655.98 psia I � Last Read (Final) 4656.25 psia �� Drawdown Start Drawdown Mobility (Invest) 56.244 and /cp 63.822 and /cp 4655.95 IL Buildup Start Drawdown Mobility (Final) d End Buildup Mud Pressure Before 5935.32 psia Mud Pressure After 5933.24 psia 4655.75 U Mud After Temperature Before /After 144.77 DEGF / 144.84 DEGF Pretest RateNolume 1.01 c3 /s / 7.54 cc 4655.55 ,� 60s Slope (Final) 0.02 psia /m 211.13 250.9 290.68 330.45 370.23 410 Pressure Variance (Final) 0.12 psia Time (sec) 56 NM NM — i — — MI MI NS • MI MN -- — MN in iIIIIIII MO Flow Regime Identification Plot : Test #11 Run 2 14040.00 ft (MD) 10058.62 ft (TVD) (Final) Schlumberger 2 -3 1e +04 0B /ME -o1 Spherical Time Function Plot : • 0 Spherical Derivative 1 4800 17 Radial Derivative j— le +0: I I I I 1e +02 , — co > . u) (3 IZ p 1e+01 rA _. U) 1 \' � Ch • d 1111 N j S U 4 ' X a', ' 211 ul1 1e -01 1:1 - — 4572 n 1 e -02 ' 3.6 2.000 0 • • 1e +00 1e +01 1e +02 Spherical Time, 1/sqrt(sec) Slope on Spherical -0.040 Delta -Time (sec) Slope on Radial 0.477 Last Buildup Pressure : 4656.25 psia Extrapolated Pressure : 4656.31 psia Buildup Mobility : 31.3 and /cp Spherical Slope : -2.18 57 Pressure Vs Time Plot : Test #12 Run 2 14038.00 ft (MD) 10056.70 ft (TVD) Schlumber er 2- 30B/ME -01 g 1 O S o O O S O O O O O N N N N a w 5 _m 9 - n a w V 000 0 G 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O C O O co a O a D o Q Q co 0 w u) a 0 7 cc K w CC O. N . a Po w a w CO 2 a a ° re a > 0 x D i _ a a a (0 Z F - 0 L < 00 a D < 00 0 0 m LL Z 1 Ft N Q O c O O O o N O O O O VO V 200 210 220 230 240 250 260 270 280 290 300 310 320 330 340 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe 0 Drawdown Start Invest. Gauge AQAP A Buildup Start Invest Formation Pressure 4656.16 psia • End Buildup Invest Last Read (Invest) 4655.92 psia Last Read (Final) 4656.23 psia Q Drawdown Start Drawdown Mobility (Invest) 33.271 md/cp 0 Buildup Start Drawdown Mobility (Final) 30.499 md/cp II End Buildup Mud Pressure Before 5926.45 psia Mud Pressure After 5927.77 psia Mud After Temperature Before /After 144.68 DEGF / 144.75 DEGF Pretest RateNolume 1 c3 /s / 7.53 cc 60s Slope (Final) 0.05 psia /m Pressure Variance (Final) 0.24 psia 58 MB 111111 111111 • NE NM 1.11 NM MI IIIIIII NM MN MN MI MN N i MI • Iii • lI • - • (= ONI IIM IMII 1.111 MII • — MI — INN 10110 Pressure Vs Time Plot : Test #12 Run 2 14038.00 ft (MD) 10056.70 ft (TVD) Schlumberger 2- 30B/ME -01 Investigation I I Final 0 0 oO o o ! — o 0 0 0 0 T • _ r _ 11 t0 LL . W a N 2 r W M I Q J d w w O N D a iY a W g w 2 I a a 0 Cf ti a V 7 - w > v - a j Q Q 0 A A 0) — H Q < 0 W cc a O U , a co • 0 F a - • a 0 3 Z 3 N LL z a Q , LL m / \ o , o o ■ N 0 0 0 0 O N 7 N N 100 200 300 400 Detail Pressure Plot Final I lI1!'f Time (sec) Tool Type FPWD675 III ! OIi ���� � � �� ■ � I II ,�� II i � III' Mud Befor Packer Type TST675 Probe 1 ii IIi 1f11 II F I1 PIII I ! I I 'n(1I do n Start Invest. I J 1 I 1 I 1 Buildup Start Invest Formation Pressure 4656.16 psia m n4656.13 ' . End Buildup Invest Last Read (Invest) 4655.92 psia r I Last Read (Final) 4656.23 psia Drawdown Start Drawdown Mobility (Invest) 33.271 md/cp N �. d. 6; Itl II 1 lit Ji ( . d. In I 1.1 �,I l l 0 Buildup Start Drawdown Mobility (Final) 30.499 md/cp 4655.93 ii lLlkl� ` ,Ii,II�I III +fit �� I ailiiiiiiiiiiiiiiiiiiiiii I � �� ��� � ( � II��f � L Mud Pressure Before 5927.77 psia lY IJ ■ End Buildup tL IYIfYY� Mud Pressure After 5927.77 psia Mud After Temperature Before /After 144.68 DEGF / 144.75 DEGF 4655.73 �� i 1�� ' 111III I ����„� +'I ■ �I�IIII Pretest a (Final) Rate/Volume 60s Slope (Fina 1 05 /s / a/m cc 4655.53 I I �I� 0.05 psi 205.56 246.65 287.74 328.83 369.91 411 Pressure Variance (Final) 0.24 psia Time (sec) 59 Flow Regime Identification Plot : Test #12 Run 2 14038.00 ft (MD) 10056.70 ft (TVD) (Final) Schlumberger 1e +0 . 2- 30B/ME -01 Spherical Time Function Plot : o Spherical Derivative - - I - -- ■■„'11' _ : ,, ;� i ' - . 111 4800 ■ � ■ ■�� ■11111 ❑ Radial Derivative 11111 ■■■111111 ■ ■■111111 ■■■IIIIH I! IIIlIIIIIIIIIIIIIIIIIIuIIIIIII -- --oI - - -- -ton - - - -- ... - -- -.too Mu ■M111111=MMEENI■M■■■••••11■■111111MMENNI •■=1 � ■■■ ■1�MI=N■■ME1� ∎�M■ ■11111 ∎�■■ ■11111 �� ■■1 MMM■■1MMMMMMEM ■1�MOMMMM■1 =U 11 11 ∎ ■ ■■■111�MI..■■111�_• ■■111 l imiiiiiiiiiiiiiiiiuiiiinii 4700 N 1 e +0 ' I .. ■■■=1..o. ■....tamilmoo co ■■111111■ ■■111111 co 2 rn N cn a 1e +01 d a , : 1e +01 I !ZF III .,. ∎MIS =IIM1 ■.,r =M■■■ ■■1 MEMI 11 ■ILA 1111`∎ ' 1EM : •■11; lil� IIIIII■■ 1e -01 1e +00 1e +01 le +02 Delta Time (sec) Slope on Spherical - 0.020 4490 n Slo on Radial - 0.453 3.6 2.000 0 Spherical Time, 1 /sqrt(sec) Last Buildup Pressure : 4656.23 psia Extrapolated Pressure : 4656.16 psia Buildup Mobility : 25.65 and /cp Spherical Slope : -2.91 60 IIM i MN M — — — NM — NM — M N — N — — — • 11111111ENIMINIIIIENI Pressure Vs Time Plot : Test #13 Run 2 14034.15 ft (MD) 10053.01 ft (TVD) Schlumberger 2- 30B /ME -01 1 Final 8 8 80 °o o O o in N N ■ V .::,.. :. :. •..0000000000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 @ LL I1 a w m m ❑ n n ii N , 0 O a 11 o < Q ( C 0 a o W J W W 11 > ❑ d d' 11 I- . ❑ 0 a r W %) 0 W a w a! W 11 • - a D C 7 < w a a II J O H F W a ft > 0 K D < < a I- 0 w Z F J a W a ❑ 0 11 d E N ° H a o D a o ❑ ❑ ❑ 0 d Z In LL a LL 11 O / \ M O O O O M MO M 300 400 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe 0 Drawdown Start Invest. Gauge AQAP 0 Buildup Start Invest Formation Pressure 4660.07 psia El End Buildup Invest Last Read (Invest) 4658.55 psia Last Read (Final) 4660.07 psia 0 Drawdown Start Drawdown Mobility (Invest) 4.341 md/cp 0 Buildup Start Drawdown Mobility (Final) 3.965 md/cp • End Buildup Mud Pressure Before 5939.67 psia Mud Pressure After 5941.04 psia • Mud After Temperature Before /After 144.37 DEGF / 144.66 DEGF Pretest RateNolume 1.02 c3 /s / 7.57 cc 60s Slope (Final) 0.04 psia /m Pressure Variance (Final) 0.54 psia 61 Pressure Vs Time Plot : Test #13 Run 2 14034.15 ft (MD) 10053.01 ft (TVD) Schlumber er 2- 30B/ME -01 Investigation I Final 0 S SO S o S 0 0 0 0 0 n n n Ill 1 - — J • 3 LL n W a m o a I /✓ . t m < • 0 2 a U W Q N I 0 O j 2' W a Co I a D w a w Q w ee O i • w w Q r _. - -- 7 K > Q d U w F- o w a w Co 0 a Co F a U a p 3 D Co 0, U z a Q , ! \ 1 O cn O O o / / \ O O O O O N N0N 100 200 300 400 4663.07 Detail Pressure Plot (Final) Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C X Packer TST675 Probe 4661.07 Drawdown Start Invest. Gauge AQAP m ■ Buildup Start Invest Formation Pressure 4660.07 psia II End Buildup Invest Last Read (Invest) 4658.55 psia 24659.07 Last Read (Final) 4660.07 psia I 0 Drawdown Start Drawdown Mobility (Invest) 4.341 md/cp 4657.07 i, • •• - • . 0 Buildup Start Drawdown Mobility (Final) 3.965 md/cp MI E nd Buildup Mud Pressure Before 5939.49 psia a Mud Pressure After 5941.04 psia 4655.07 - • Mud Af ter Temperature Before /After 144.37 DEGF / 144.66 DEGF Pretest Rate/Volume 1.02 c3 /s / 7.57 cc 4653.07 n 60s Slope (Final) 0.04 psia /m 254.06 291.05 328.04 365.03 402.01 Pressure Variance (Final) 0.54 psia Time (sec) 62 IIIII MI OIMI I MI NM • MI NM • MI MO r• NM MN NM — • MI — ! — — — MI OM I MD — MI — MB Flow Regime Identification Plot : Test #13 Run 2 14034.15 ft (MD) 10053.01 ft (TVD) (Final) Schlumberger 1e +04 2 -30B /ME -01 - d Spherical Derivative — �MMEN• =IIIIM ' - -, - -' — ❑ Radial Derivative ■MI•■■■■UMINMEI=• - _ lipi II r.1 IIL I 1 e +0" hr.■■• i ____o.■1■■■■ 111 - n■ma:wimm NE ■4. " 'w _�M ■ ■ ■ ■� _dam 111 11 cll CO co 2 co �!�� CL 1e+01 Ill ILO ■■■ M= ! 1111 L: I:�: /. ■ F, .. MI II * 1e +Oe ❑ 0 III • • 1e - 1e +00 1e +01 1e +02 Delta -Time (sec) 63 Pressure Vs Time Plot : Test #14 Run 2 14002.00 ft (MD) 10022.20 ft (TVD) Schlumberger 2- 30B/ME -01 O o o0 O O N O O co co co O V V V ..:: :12u•■••000O00 0 0 0 0 ) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ii • LL (w d w N N D N 1- a u a O a 0 a as N O w NI Q 11 ❑ cr w W F a 7 D 5 w w W a w w < m a w o 0 - a r- F Q 0 ❑ Q 3 Q ❑ O a 0) 0 a Q 0 ❑ z 3 N LL Z Q LL O 0 0 O O 0 0 g3 r MO 220 230 240 250 260 270 280 290 Time (sec) Tool Type FPWD675 Mud Before Test Type Type 2 - C Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4644.24 psia • End Buildup Invest Last Read (Invest) 4644.21 psia Drawdown Start Last Read (Final) 4644.24 psia Drawdown Mobility (Invest) 6.273 md/cp Buildup Start Drawdown Mobility (Final) 6.883 md/cp End Buildup Mud Pressure Before 5925.1 psia El Mud Pressure After 5923.59 psia Mud After Temperature Before /After 144.52 DEGF / 144.73 DEGF Pretest RateNolume 1 c3 /s / 7.42 cc 60s Slope (Final) 0.01 psia /m Pressure Variance (Final) 0.22 psia 64 • MI • r — — — i — — — — — — — — — • • MB 111. MI MI IIIIII IIIIII IIIII MN NM III. MB INN IIM IIIM MN 1.1111 NM INN 111. Pressure Vs Time Plot : Test #14 Run 2 14002.00 ft (MD) 10022.20 ft (TVD) Schiumberger 2- 30B /ME -01 Investigation 1 1 Final o o 8 0 8 o - o 0 o 0 0 1 � r • W LL a' w m m 0 a n n n ¢ o a U Q Q d w 0 I Q o w w O co D a LY E co I- 0 w w 2 w a U w m _i a 0 a O ¢ ¢ a D co Z D ' d Ill Q F- ' Q W cr d o O CL N O r Q Z , LL z a Q LL 0 M / \ N N 't / \ O N NQ N ____-- 100 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type FPWD675 4644.34 1=11111111111111111111111111111111M11111111 Test Type Type 2 C Mud Before I ��111 1 Ill I �1 1 1 11 11!r Tirl Packer TST675 Probe DrawdoStart Invest. Gauge AQAP b 'nn� ��Af ■ �■ �l • Buildup Start Invest Formation Pressure 4644.24 psia �, l I FPI!! 111 1111111110111111 I Ih �� 11� 1 End Buildup Invest Last Read (Invest) 4644.21 psia 4644.14 ^^, I i I r i I .i Last Read (Final) 4644.24 psia 1.11 II I 0 Drawdown Start Drawdown Mobility (Invest) 6.273 md/cp O I 0 Buildup Start Drawdown Mobility (Final) 6.883 md/cp 4643.94 i E nd Buildup Mud Pressure Before 5925.1 psia a ` Mud Pressure After 5923.77 psia 4643.74 I I I ' , 1 I .I 1 l l I r [ l i ' i l l II i i I 14 , I I I. i i r ' i I i ilIJ I , i i I ' L i l l I 1 . 1 ,tl IN Mud After Temperature Before /After 144.52 DEGF / 144.73 DEGF 4643.54 11 IIIiilI iiiiiikillilliilifiligidifilkill I.111Jllrl Pressure Variance (Final) 0.22 psia 01 /m 2 cc 219.06 257.45 295.84 334.23 372.61 411 Time (sec) 65 Flow Regime Identification Plot : Test #14 Run 2 14002.00 ft (MD) 10022.20 ft (TVD) (Final) Schlumberger 1e+04 2-30B/ME-01 0 Denvahve - - - 0 Radial Denvative i - 1e +0: • C,/ 1 e +0� � _.__ CD N 0 - d l e +01 1 n F ] I le -01 1 +00 1 e +01 le +02 Delta -Time (sec) 66 • NM IN I — — — — — 1• OM • • • • • OM • MI 111. IIIII•1 111•1 NM (♦ OM MI OM • MIN 11111111 MI IIIIII 1.11 111. 111. IIM 111. 111. Pressure Vs Time Plot : Test #15 Run 2 13984.20 ft (MD) 10005.15 ft (TVD) Schlumberger 2-30B/ME-01 I 8 8 0 8 o N- C am:0003000000000000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 is LL c U n w � m a_ 0 a a 0 R a a 2 a U ul ¢ u' Q d 2 ,c w > (0 D a s w N g D IC rr W a w w O • Q - a r w Z 0 0 0 W I< 0 0 O a CO i C V J F ¢ I ¢ 0 0 0 - . Z co LL a LL ■ 0 M ______\,,,, . o .. O LO O O O 4 4 V 220 230 240 250 260 270 280 290 300 310 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4631 psia • End Buildup Invest Last Read (Invest) 4630.8 psia Last Read (Final) 4631 psia Drawdown Start Q Drawdown Mobility (Invest) 38.588 md/cp A Buildup Start Drawdown Mobility (Final) 25.089 md/cp • End Buildup Mud Pressure Before 5906.76 psia Mud Pressure After 5903.99 psia IN Mud After Temperature Before /After 144.63 DEGF / 144.72 DEGF Pretest Rate/Volume 1.13 c3 /s / 7.33 cc 60s Slope (Final) 0.01 psia /m Pressure Variance (Final) 0.13 psia 67 Pressure Vs Time Plot : Test #15 Run 2 13984.20 ft (MD) 10005.15 ft (TVD) Schiumber er 2- 30B/ME -01 9 Investigation I I Final 0 0 0 n n liK''' a 4 • i .. W LL a W m / m a. a a < F i < 0 2 a U W Q (n 0 z j D W a a w qa w . ,-- w a i W O w E ii o i I- W a - > 0 < a F N Z 0 -I 0 W F 0 Q A 0 K 1- Q 0 0 LL y 0 , a 3 a 0 3 l D 0 a_ — — QI O. LL I I I o C o o 0 / 7 N o N o N N ON 100 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type I ype FPWD675 Mud Before Test Type Type 2 - C X Packer TST675 Probe Drawdown Start Invest. 4631.1 Gauge AQAP B uildup Start Invest For mation Pressure 4631 psia m p n4630.9 End Buildup Invest Last Read (Invest) 4630.8 psia T�gripplrlprritrirrrpirrirr171 f 'nil o1 Drawdown Start Last Read (Final) 4631 psia Drawdown Mobility (Invest) 38.588 md/cp 4630.7 , I I Buildup Start Drawdown Mobility (Final) 25.089 md/cp tl u i 1�, I I J, `1 , l `� +� ,�, y JJ II ''LL L� ��JJ �I , llII End Buildup Mud Pressure Before 5906.76 psia d AIII •l 1411�� 1ta iill iiiiiii iYlii.lidi kl{WYijkl E 1illa il[iWiillEall • Mud After Mud Pressure After 5903.99 psia 4630.5 Temperature Before /After 144.63 DEGF / 144.72 DEGF n I Pretest RateNolume 1.13 c3 /s / 7.33 cc 4630.3 60s Slope (Final) 0.01 psia /m 217 255.6 294.2 332.8 371.4 Pressure Variance (Final) 0.13 psia Time (sec) 68 • IIIM IIIIII NIN 1111. • alle 111111 = MI MN 111111 OM MI • ONII 1 MI • -- NM — MI OM N - - -- I• — I MI Flow Regime Identification Plot : Test #15 Run 2 13984.20 ft (MD) 10005.15 ft (TVD) (Final) Schlumberger t e +o 2-30B/ME-0 1 I .. ■ ■■ ��.. ■ ■■ O Spherical Derivat ■••••11111■ EMME ■ 0 Radial Denvahve f E11•11•11■∎ ∎■ ■■___II_■ ■ ■■■ ■■ ■1■ ■■■■ ■1■■■■■ 1 e +0 , lIII ■ ■ ■�� ■ ■ ■ ■�I ∎M11111111111■■ 11∎MMIM■ ■■■■ 11111111111,7401 111111111111111 ■IIIIIIIiI ■■C. ■ ■ ■� `s1 ... ���.. ■ ■ ■����.. ■.. ∎M• "■■r' ‘41Pr''l Ak' iiiiiu �� ■■ ■111! a '''' F ,� ■ ■ ■1111�� ■ ■�IIII M•1viii'=:': ■ ' ° r ` .111111ral 11111411111 11111.111111 1e -0 1e +00 1e +01 1e+02 Delta -Time (sec) 69 Pressure Vs Time Plot : Test #16 Run 2 13977.84 ft (MD) 9999.06 ft (TVD) Schlumber er 2- 30B/ME -01 I O O O D O - - o 0 1 11 11 1 p.' W N N 1 O N m L' Q d 2 Q 1 U Iql ?C W 0 7 (Y w W 11 F 7 d 7 d H 2 w q� m w O w t w • d 0 CC N a J • z w 17 J W O > a a a F U w • = F o w < f7 O Q_ CO d 1- a a o 3 Z 3 N W Z IL Q , O O ° o O O O O O N N O c r th M 210 220 230 240 250 260 270 280 290 300 310 320 330 340 350 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe V Drawdown Start Invest. Gauge AQAP 0 Buildup Start Invest Formation Pressure 4628.53 psia El End Buildup Invest Last Read (Invest) 4628.04 psia X Drawdown Start Last Read (Final) 4628.53 psia Drawdown Mobility (Invest) 5.565 md/cp Buildup Start Drawdown Mobility (Final) 5.368 md/cp • End Buildup Mud Pressure Before 5901.87 psia Mud After Mud Pressure After 5898.69 psia Temperature Before /After 144.45 DEGF / 144.68 DEGF Pretest Rate/Volume 1 c3 /s / 7.35 cc 60s Slope (Final) -.08 psia /m Pressure Variance (Final) 0.82 psia 70 • MI • 1111 • MI • MI NM OM NM OM 111111 1.11 IlM I♦ MI INE EN OM i' NM Pressure Vs Time Plot : Test #16 Run 2 13977.84 ft (MD) 9999.06 ft (TVD) Schlumberger 2- 30B /ME -01 I Investigation I I Final o o 00 0 o - 0 0 0 0 o t0 W ( a w T. a a 0 ' 2 a ci ¢ : 0 2 Q U a (1)1 < W J a uJ W > N D a iY a (/) � D 0 r Lk' w rn w a w a w M < w a • V 0 • U r 2 j r - / _ ■!-: 1 1 _ a a a I- ii w Z J a �i 0 0 t I w Q 0 U, 0 SC_ (0 !o F Z 3 N 0 Z a - 1/4 0 M / o N 7 ND `,`,' Z N 100 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type FPWD675 4628.83 I WI II lin Hi III 11 ' I 1 !! I l i 1 r i H I I 1 X Mud Before Packer pe TST675 Probe X Drawdown Start Invest. Gauge AQAP 4628.63 , l B uildup Start Invest ea ( ) psia Pressure 4628.53 psia iii ill I I i 1 11 1 1 II I f I End Buildup Invest Last Rd (Invest) six 34628.43 �p I I I Last Read (Final) 4628.53 psia 2 .I ''I I ' Dr awdown Start Drawdown Mobility (Inves 5.565 md/cp 24628.23 'I 0 Buildup Start Drawdown Mobility (Final) 5.368 md/cp III 1 I • End Buildup Mud Pressure Before 5901.87 psia cL p Mud Pressure After 5898.69 psia 4628.03 ; • M Mud After Temperature Before /After 144.45 DEGF / 144.68 DEGF . 11 I Pretest RateNolume 1 c3 /s / 7.35 cc 60s Slope (Final) -.08 psia /m 4627.83 216.56 255.05 293.54 332.03 370.51 Pressure Variance (Final) 0.82 psia Time (sec) 71 Flow Regime Identification Plot : Test #16 Run 2 13977.84 ft (MD) 9999.06 ft (TVD) (Final) Schlumberger 1e+0 2-30B/ME-01 r_ _L:=�■■1�__■1EM __■...0 __ii - d Spherical Derivative _ 0 Radial Derivative ■__E■ ~ __EN■■ — __ -■ � IM ■ i` 1111 EMI IIIIIIII1 Mill lip 111111 11110 11111 1e +0 _Ulr■lr ___om■.• ■___.. ■.•— ___mm ■.1 ■■ ■■hii- ;� •:•4. ■■■11111 ■�■111111 1■■ ■■111 ■ v 1111M■■11111 .■111111 11111111 ■■11111 ■■■11111 •■■11111 co F .` p 1e +0. ;:I IIIIIIIIIIIIIIIIIIIIIIIII 22 __■■M . ° A■■11IN ..111111 .11111111 22 MENU , ■MIe1I 11•1•111011111 M1111•11111111 MEW ; . ■1I1 =ME M 111111 � ■■111111 ■■■11111 \6 4 11111111 1 IIIII 1e +01 IC II pii; =MEE_ ___ Ell ii �. ■ ■11��MIMIMM■■N ��__M■ 11::7 ��j __�MM1∎M __E■■■I �___ ■1. W4 ___ ■ ■ ■ ■II♦__ ■I•■■ I 111111 111! - 1 1e +01 1e +00 1e +01 1e +02 Delta -Time (sec) 72 ■ INO SMO 111011 1.11 NM IIIIII ■ MI MI ■ S IMI MO e IIMI MI 1111 e UM IN — MI MI NM 111. MN NM IIIIII I NM 11.11 MO I I♦ MN OM MB Pressure Vs Time Plot : Test #17 Run 2 13973.92 ft (MD) 9995.30 ft (TVD) Schlumberger 2- 30B /ME -01 oO o 1 cn l'o M t•0 CO er V V .0 LL a W m m 0 n N Q J K I W w 0 W a to a 7 g3 w a w i t W N a w a a W Z F J Q 0 0 w ▪ F Q 0 U ix a w 0 r D U o 0 — I < 0 Z N LL LL • 0 M CU rn m IA N N O O O O O V - 00 V 210 220 230 240 250 260 270 280 290 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe V Drawdown Start Invest. Gauge AQAP A Buildup Start Invest Formation Pressure 4626.63 psia • End Buildup Invest Last Read (Invest) 4626.52 psia Last Read (Final) 4626.63 psia 0 Drawdown Start Drawdown Mobility (Invest) 594.345 md/cp 0 Buildup Start Drawdown Mobility (Final) 782.653 md/cp • End Buildup Mud Pressure Before 5903.44 psia Mud Pressure After 5904.95 psia II Mud After Temperature Before /After 144.66 DEGF / 144.77 DEGF Pretest Rate/Volume 1 c3 /s / 7.37 cc 60s Slope (Final) 2.40E -03 psia /m Pressure Variance (Final) 0.09 psia 73 Pressure Vs Time Plot : Test #17 Run 2 13973.92 ft (MD) 9995.30 ft (TVD) Schlumberger 2- 30B /ME -01 1 Investigation 1 1 Final I. 3 0 80 3 o — o O CO m co CD co . • W m N 0 0 n n , < • 0 LL ¢ U Q w N1 d z w w rn a S LL w a u a w 2 a 7 CC 5, a w 1- • 0 < a , , U w Z o < in 0 0 O a co O 1 0 • a 0 0 Z 3 co Cl_ Z a Q LL O O 0 0 / / O 0 0 0 ' 0 O V R V _ 100 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type FPWD675 4626.93 • Mud Before Test Type Type 2 - C . Drawdown Start Invest Packer TST675 Probe 4626.73 1iorr"!'m� 1Ir!I' lT. O R pi 11 '11• r'!!. ", , h .. Gauge AQAP Buildu Start Invest P Formation Pressure 4626.63 psia 04626.53 -' 1 ih.Ltu.JIJJu VJdi ✓ i d�i Lii1LLiI/Wail ii ii I � Alt �il,j ld • End Buildup Invest Last Read (Invest) 4626.52 psia 0 Drawdown Start Last Read (Final) 4626.63 psia A Buildup Drawdown Mobility (Final)t) 594.345 md/cp p St 782.653 and /cp x4626.3 "- Ill End Buildup M ud Pressure Before 5903.44 psia Mud Pressure After 5904.95 psia 4626.13 "— • Mud After Temperature Before /After 144.66 DEGF / 144.77 DEGF Pretest RateNolume 1 c3 /s / 7.37 cc 4625.93 60s Slope (Final) 2.40E -03 psia /m 210.56 250.25 289.94 329.63 369.31 409 Pressure Variance (Final) 0.09 psia Time (sec) 74 MI — MI — MI — II MI • — r MI — — — MI MI MI 1.1 — NM NM • NM — — r MI MI NM 111111 IIIIIII Flow Regime Identification Plot : Test #17 Run 2 13973.92 ft (MD) 9995.30 ft (TVD) (Final) Schlumberger 1e 2- 30B/ME -01 _; Spherical Denvative ❑ Radial Denvative u ::._ 1e +01 1e +OG (i) p 1e -01 p to 1e 02 � le -02 1e -04 1e +00 1e +01 1e+02 Delta -Time (sec) 75 Pressure Vs Time Plot : Test #18 Run 2 13962.21 ft (MD) 9984.09 ft (TVD) Scblumber 2- 30B/ME -01 ger N , N I ,' m ' ,,,,,,, ..11:100.•• •000600000C 0 0 0 0 0 0 0 0 0 0 C 0 0 0 0 0 0 0 0 O e O O V a c 0 0 0 0 0 0 0 :01 LL 0 t 1 N - 0 a o a s o g 0 .. 0 U < 0 2 0 w i .5 O 5 k W w 0 y a- a a 0 w Lir a t K w 1 a O = F w < ¢ a r- ~ - U w Z t _, < < 0 0 a y o ,_ a J < . Z LL LL h 0) n LI m .3 , m 0 N N � N 210 220 230 240 250 260 270 280 290 300 310 320 330 340 350 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4623.36 psia El End Buildup Invest Last Read (Invest) 4622.1 psia X Drawdown Start Last Read (Final) 4623.36 psia Drawdown Mobility (Invest) 3.889 md/cp Buildup Start Drawdown Mobility (Final) 3.801 md/cp • End Buildup Mud Pressure Before 5911.07 psia Mud Pressure After 5912.44 psia Mud After Temperature Before /After 144.46 DEGF / 144.81 DEGF Pretest Rate/Volume 0.99 c3 /s / 7.51 cc 60s Slope (Final) 0.04 psia /m Pressure Variance (Final) 0.57 psia 76 MI IIIII ® 1111. MI I MI MI I• • OM I= OM • • I= MI MI MN IM NE I • I MN IIM OM NM OM • I I— • NIM Pressure Vs Time Plot : Test #18 Run 2 13962.21 ft (MD) 9984.09 ft (TVD) Schlumberger 2- 30B/ME -01 I Investigation I 1 Final O O OO O O N O O O O O n r r 4 EL- d W N u 1 • a a M Q • 0 2 Q 5,--) Q WI O - w O � 0 w a c w w of w a '. w Cr a • w a w i a ,.,., .... ..._ 7 0 ) Z < J Q w Q r o F ¢ o O r .. . - a N 0 r a J Q 0 0 11 0 Z 0 a 0 Z a n Q a 11 11 11 11 A O O O O / O O O O O N 7 NO N N 1 100 200 300 400 Detail Pressure Plot (Final) Time (sec) Tool Type FPWD675 4626.36 Mud Before T Type Type 2 - C Packer TST675 Probe Drawdown Start Invest. 4624.36 Gauge AQAP Buildup Start Invest Formation Pressure 4623.36 psia L ast Read (Invest) 4622.1 psia 04622.36 End Buildup Invest ( ) p Last Read (Final) 4623.36 psia D rawdown Start � � � i � 0 Drawdown Mobility (Invest) 3.889 md/cp m • 0 Buildup Start Drawdown Mobility (Final) 3.801 md/cp 4620.36 ►; End Buildup Mud Pressure Before 5911.07 psia o_ u Mud Pressure After 5912.44 psia 4618.36 • Mud After Temperature Before /After 144.46 DEGF / 144.81 DEGF Pretest Rate/Volume 0.99 c3 /s / 7.51 cc 0 60s Slope (Final) 0.04 psia/m 4616.36 Pressure Variance (Final) 0.57 psia 214.69 253.75 292.81 331.88 370.94 410 Time (sec) 77 Flow Regime Identification Plot : Test #18 Run 2 13962.21 ft (MD) 9984.09 ft (TVD) (Final) Schlumberger 1e+0,1. 2-30B/ME-01 1 1 Spherical Deavative - 0 Radial Derivative I II ,.. • it 1U' 1 e +0: �� �!1;i e ""ice, I■ i 1111 I; ;. . "� 4! I. ; ! o 1 e +OZ -- . O N r —. n 2 Y LJ t 1 EP I i N 0 1e +01 • • • N''< * • MNMI � MME•■NM - - - MEM 1I • II;' "J 1 .J 1e +00 1e +00 1e +01 1e +02 Delta -Time (sec) 78 MI NM MI MI MI r MN MB NI MI MI MO • Mil MB INNO -- MN • — r NM 111. — — • MI Ni. — UM MS — — MI — MN Pressure Vs Time Plot : Test #19 Run 2 13956.81 ft (MD) 9978.92 ft (TVD) Schlumberger 2- 30B/ME -01 I 11) - N W ‘r V ,i- 1 V "00"000000 0 0 0 0 0 0 0 0 0 0 0 0 G 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 11 11 11 — 11 W LL a 9 d d 11 U < Q y 0 u w In Q - - w w 1 > co o , re IL - In L 0 w w 0 ii w a i 0 UJ 7 C- m IL li w o < < a H w Z IR Q ❑ 0 W a', ❑ O a c 0 r a O a 0 Z 0 LL Z d • w o -iL N N N O o _1') F m0 M 220 230 240 250 260 270 280 290 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe 0 Drawdown Start Invest. Gauge AQAP 0 Buildup Start Invest Formation Pressure 4619.67 psia • End Buildup Invest Last Read (Invest) 4618.99 psia Last Read (Final) 4619.67 psia Drawdown Start Q Drawdown Mobility (Invest) 4.58 md/cp 0 Buildup Start Drawdown Mobility (Final) 5.517 md/cp III End Buildup Mud Pressure Before 5906.7 psia Mud Pressure After 5906.69 psia • Mud After Temperature Before /After 144.59 DEGF / 144.84 DEGF Pretest RateNolume 1.01 c3 /s / 7.35 cc 60s Slope (Final) -.01 psia /m Pressure Variance (Final) 0.45 psia 79 Pressure Vs Time Plot : Test #19 Run 2 13956.81 ft (MD) 9978.92 ft (TVD) Schlumberger 2- 30B/ME -01 I Investigation l 1 Final o o oO o o — O o o o 0 r � r . „ ..._____________ . ilk ,. LL I W m y - a M a a 2 a U w U d co J d ' W W j a cc w a a. D w J a ai a Lu O > ¢ Q a U F Z U p ¢ 11111!"11111 Lu ¢ W a a N a I- ¢ J Q 0 Z LL ' LL II 1 ¢ LL A O / O O O O O N NO N \ 100 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type FPWD675 4619.97 i I l I II I I' f( I r l Mud Before Test T e T e 2- C I I 1 � 11 �I I II 1 III) �I I'' � I �' YP S l I 1 Packer TST675 Probe D Start Invest. 4619.77 I I I , Gauge AQAP II , Buildup Start Invest Formation Pressure 4619.67 psia .N �� ' L ast Read (Invest) End Bui ldup Invest ( ) 4618.99 psia 04619.57 Last Read (Final) 4619.67 psia 0 Drawdown Start Drawdown Mobility (Invest) 4.58 md/cp 4619.37 0 Buildup Start Drawdown Mobility (Final) 5.517 md/cp 2 • End Buildup Mud Pressure Before 5906.7 psia 1 J Mud Pressure After 5906.69 psia 4619.17 III 111 I I.1 I n 11J l L 1. i 1 • Mud After Ai II I'I II + J Temperature Before /After 144.59 DEGF / 144.84 DEGF n 111 ` 11 l 111 �!, I `` �� Ill ll'I t J till 1u �14 I ll'�li ,� ,I h ,I,i Rate/Volume Pretest Rateolume 60s Slope (Final) 1.01 c3 /s / 7.35 cc -.01 psia /m 4618.97 ILI (Final) Variance 219.19 257.75 296.31 334.88 373.44 412 ( ) 0.45 psia Time (sec) 80 • • an NIRO NM MN NM MO OM MI I MB OM MI MB MB E O 11•111 IIIIIII 1111111 IIIIIIII 11110 1.11 • Flow Regime Identification Plot : Test #19 Run 2 13956.81 ft (MD) 9978.92 ft (TVD) (Final) Schlumberger 2- 30B /ME -01 1e +04 O Spherical Derivative - i — ❑ Radial Denvative 4' 1e +0: 111 •;, 4 •,•■ sod q4 1e +02 • - 11 > N p 1e +01 • ICI • 1e +. 1 11 • le -01 • le -02 le +00 1e +01 1e +02 Delta -Time (sec) 81 Pressure Vs Time Plot : Test #20 Run 2 13947.29 ft (MD) 9969.80 ft (TVD) Schlumber er 2- 30B/ME -01 g Investigation 1 I Final 0 0 0 0 o O Ln O O O o 0 0 0 a LL p a w W a a o a • m CO F co < i t . ¢ 0 w w Q ¢ O = it w - II , U a w w 12 w a a w w E _, -, a x ¢ a O U v i- c ¢ z ¢ o [ r w 8 a V) w 0 ¢ U • z U D O a z O a a ¢ LL LL O O O O O 100 200 400 Time (sec) Tool Type FPWD675 i♦ Mud Before Test Type Dry Test Packer TST675 Probe V Drawdown Start Invest. Gauge AQAP A Buildup Start Invest Formation Pressure psia • End Buildup Invest Last Read (Invest) 496.06 psia 0 Drawdown Start Last Read (Final) 179.28 psia Mud Pressure Before 5891.53 psia A Buildup Start Mud Pressure After 5890.59 psia • End Buildup Temperature Before /After 144.19 DEGF / 144.7 DEGF Pretest Rate/Volume 0.3 c3 /s / 3.04 cc Mud after 60s Slope (Final) 21.02 psia /m Pressure Variance (Final) 0.03 psia 82 MI • 11.1 GM MI INN .111 NM 11.1111 1.11 I•111 MN MI IIIIII IIIIO INE Mil 111111 IMII • • IIIIIII NM an MN • 11111.1 IIIII1i En NM NM ille IIM 1110 I•1111 UM MIN 11111 Pressure Vs Time Plot : Test #21 Run 2 13948.97 ft (MD) 9971.41 ft (TVD) Schiumberger 2- 30B /ME -01 I M el co er v v I g LL a w m N a_ 9—, 0 a a H 0 2< • V # :cco0000000 0 0 0 0 0 0 0 0 0 o C o 0 0 C 0 0 o e o o- 0 0 0 0 0 0 0 w rd a . o LL' W W o • CO D . a CC d i W N W LL W W 2 _1 a 0 a J W 2 J > W 0 ] d D 03 Z ' ' V _ — J < ❑ V, W ▪ < ❑ a a N O . 1- 0 D a 0 3 Z 0) LL a • LL M ✓ V V 6 N N a O V V o R X RO 4 230 240 250 260 270 280 290 300 310 320 330 340 350 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe X Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4617.15 psia Ill End Buildup Invest Last Read (Invest) 4616.82 psia Last Read (Final) 4616.16 psia 0 Drawdown Start Drawdown Mobility (Invest) 42.87 md/cp 0 Buildup Start Drawdown Mobility (Final) 22.647 md/cp • End Buildup Mud Pressure Before 5904.58 psia Mud Pressure After 5904.05 psia • Mud After Temperature Before /After 145.02 DEGF / 145.13 DEGF Pretest RateNolume 0.99 c3 /s / 7.37 cc 60s Slope (Final) 0.01 psia /m Pressure Variance (Final) 0.45 psia 83 Pressure Vs Time Plot : Test #21 Run 2 13948.97 ft (MD) 9971.41 ft (TVD) Schlumberger 2- 30B/ME -01 9 Investigation I Final 0 0 oO o o u> o o o 0 0 • .; .-1 _ ■ N LL 1 0. W N N 0 2. - o, a a 0 a Y., a W (40,1 d - W w > 0 0 a CC w a � it w CL 0 d' N a o U _, c, j enr-y------7.=IF i .99€09eGeee.e.a-e-e-e-e-e-e-e-c—e--. < < a , U F U a 0 H a w o a y o F a _J a 0 z 0 U) LL z a a , 0 m 0 0 0 0 o o / / N NQ N 100 200 300 400 500 4619.16 Detail Pressure Plot (Final) Time (sec) Tool Type FPWD675 • . Mud Before Test Type Type 2 - C Drawdown Start Invest. Packer TST675 Probe 4617.16 Gauge AQAP Te (u Buildup Start Invest Formation Pressure 4617.15 psia 24615.16 . End Buildup Invest Last Read (Invest) 4616.82 psia Last Read (Final) 4616.16 psia V Drawdown Start Drawdown Mobility (Invest) 42.87 and /cp 0 Buildup Start Drawdown Mobility (Final) Mu Pressure Before ) 22.647 and / 5904.58 sia End Buildup p a Mud Pressure After 5904.05 psia 4611.16 / Mud After Temperature Before /After 145.02 DEGF / 145.13 DEGF Pretest RateNolume 0.99 c3 /s / 7.37 cc 4609.16 60s Slope (Final) 0.01 psia /m 240.38 280.3 320.23 360.15 400.08 Pressure Variance (Final) 0.45 psia Time (sec) 84 • N in — IIMI 11111. NM INO NM OM I• NM MN MI MI NM MI NM NM IIIIII MN ME MI 11.1 MN NM 1111. 111111 MN IIIIII MI il= 111111 MI IMI NM INI Flow Regime Identification Plot : Test #21 Run 2 13948.97 ft (MD) 9971.41 ft (TVD) (Final) Schlumberger 2- 30B /ME -01 Spherical Time Function Plot : 1e +o4 - _— - 4700 0 Spherical Derivative , - ID Radial Derivative 1 • 1e +0: cP A.m. .. 4600 1e +02 I (0 (1) tD .� _1 Q 2 L p 1 e +01 .. , _ _ . .... N a) . . rn v I d co 0) ^ L LL v 1 e +0G *I'd �� 4 1 ir r N i V.1 %.»•. inp 1 e -01 0 1 4380, r'1 1 3.6 2 .000 0 1e -Oc 1e +00 1e +01 1e +02 Spherical Time, 1/sqrt(sec) Slope on Spherical -0.045 Delta Time (sec) Slope on Radial 0.454 Last Buildup Pressure : 4616.16 psia Extrapolated Pressure : 4617.15 psia Buildup Mobility : 24.94 and /cp Spherical Slope : -3.02 85 Pressure Vs Time Plot : Test #22 Run 2 13940.83 ft (MD) 9963.61 ft (TVD) Schlumber er 2- 30B /ME -01 g o co o 0 N LL T. W m O n • < 0 < 0 E Q () W a WI 0 W W u) 7 a w 1— a W m D a a OOOOOOOOOOO 00 0 0 0 0 0 O O O O O (Y O © E O O O -0 O O N > 0 ( j ▪ < < a r V w o /11 • o a D O FE 0, 0 a • a 0 D 0 c0 0. z Si_ a O m _ N N N N N O V - VO p 210 220 230 240 250 260 270 Time (sec) Tool Type FPWD675 Mud Before Test Type Type 2 - C Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4613.53 psia End Buildup Invest Last Read (Invest) 4613.46 psia Q Drawdown Start Last Read (Final) 4613.53 psia Buildup Start Drawdown Mobility (Invest) 123.417 md/cp Drawdown Mobility (Final) 139.951 md/cp End Buildup Mud Pressure Before 5883.61 psia Mud Pressure After 5883.53 psia Mud After Temperature Before /After 144.95 DEGF / 145.02 DEGF Pretest Rate/Volume 1 c3 /s / 7.37 cc 60s Slope (Final) -.02 psia /m Pressure Variance (Final) 0.17 psia 86 • • • NM 111.1 IIIIIII IIIIIII MI M NIMI • 1.11 1110 = — MI MI — — — — ! — I I — — — NM — MN • Pressure Vs Time Plot : Test #22 Run 2 13940.83 ft (MD) 9963.61 ft (TVD) Schlumberger 2- 30B/ME -01 Investigation n Final O 0 oO o 0 O 0 0 0 0 n , , n 1 t _ . .- - All#4 III - L- / • W m R o- n N ¢ o a U ¢ Q c ri) I Y W � Q J 0 W W > w j a C Q! W o W 0 w • J d 7 K a j O 7 W W J • .< a a r N Z D Q W i Q ❑ CI 0 o a u) 0 F U¢ J • Q p 3 D 0 LL z a W 0 N 0 0 0 °o z O N NQ N _. 100 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type FPWD675 4613.83 1 n �� (I I( T est Type T e 2- C WIT, 111;, ��11(11 !! ��� I IMII � ,IT �IT I I MII' � ' ����I Mud Before yp Packer TS T675 Probe Drawdown Start Invest. Gauge AQAP 4613.63 r I , ] Buildup Start Invest Formation Pressure 4613.53 psia N i I MI End Buildup Invest Last Read (Invest) 4613.46 psia 04613.43 I Last Read (Final) 4613.53 psia I t1 Drawdown Start Drawdown Mobility (Invest) 123.417 md/cp 4613. jiI � � �l�ui�����1I I y LIMlhi �i I IIV I iilki lIl Buildup Start Drawdown Mobility (Final) 139.951 md/cp iii 0) � ' � End Buildup Mud Pressure Before 5883.61 psis a Mud Pressure After 5883.53 psis 4613.03 Mud After Temperature Before /After 144.95 DEGF / 145.02 DEGF II 60s Slope (Final) Pretest RateNolume 1 c3 /s / 7.37 cc -.02 4612.83 210.63 250.3 289.98 329.65 369.33 Pressure Variance (Final) 0.17 psia m Time (sec) 87 Flow Regime Identification Plot : Test #22 Run 2 13940.83 ft (MD) 9963.61 ft (TVD) (Final) Schlumberger t e +0 2-30B/ME-01 I m.. — Spherical Derivative _ , ____ - MNp 0 Radial Derivative . - - - INIM I 1 - rT z\i, 1 e +0. e I 1e +01 I I 0 > 5 — 0 1e +01 N • 7 A re v 0 • Alhl le -01 \ � 41' 41 .. C n , I 1 *A di Ij1 1e -0. I 1e -0 1e +00 1e +01 1e +02 Delta -Time (sec) 88 MI I E OM • = I I= • — MI — • • — — • • MI MI NM I= MN MI MI Iii IM MIN MII — IIM OM MS • 111.1 IMIN IMO Pressure Vs Time Plot : Test #23 Run 2 13936.56 ft (MD) 9959.52 ft (TVD) Schlumberger 2- 30B/ME -01 Final 1 cil o o2Q M cd u' cd m CV N N C` n _ O O O i O O Ili a O n' w m m O n a O CI- F., < 0 2 Q 0 U Q W I Q W J Q! W W O to D a C 2 w w N w a w 00 w 2 _1 a ❑ n a J W V) O • 0 - ,a j < a I- W - F J < ❑ 0 I- 0 ❑ o d N a F U¢ J • Q O z ' , cn LL Z a Q , O CO N N N 6 6 6 ..-- --- V ------re N O N N O N MDR, 200 300 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe Drawdown Start Invest Gauge AQAP Buildup Start Invest Formation Pressure 4612.63 psia • End Buildup Invest Last Read (Invest) 4612.54 psia Last Read (Final) 4612.63 psia Drawdown Start Drawdown Mobility (Invest) 3.258 md/cp Buildup Start Drawdown Mobility (Final) 3.903 md/cp • End Buildup Mud Pressure Before 5895.35 psia Mud Pressure After 5897.02 psia • Mud After Temperature Before /After 144.61 DEGF / 144.81 DEGF Pretest Rate/Volume 1 c3 /s / 14.88 cc 60s Slope (Final) 0.19 psia /m Pressure Variance (Final) 2.27 psia 89 Pressure Vs Time Plot : Test #23 Run 2 13936.56 ft (MD) 9959.52 ft (TVD) Schlumberger 2- 30B/ME -01 Ilnvestigatiori I Final 0 0 00 0 o - 0 0 0 0 0 r n n /#4 a Q a a I I a �- a n m a U 2 0 U Q N < W O S w W Li > 0 � a Ce H cn a w ~ 0 ■ Q W W 0_ w X w n a j 7 W U J > U ��� r Q Q d H W Z F U Q L a o a a N O F ¢ 0 U U 3 O z 3 m u_ Z a Q u _ O m 0 0 0 / \ o O N o N0 N 100 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type FPWD675 4612.93 I I I I I (,1 h I) n I n, 1 I II I I I Mud Before Pact Type Type 2- C Ir i l Packer TST675 Probe Drawdown Start Invest. 4612.73 I 1 ( ! l ' I I :Co- Gauge AQAP Buildup Start Invest Formation Pressure Last Read Invest 4612.63 psia 84612.53 . End B uildu p Inv ( ) 4612.54 p psis Last Read (Final) 4612.63 psia j Drawdown Start Drawdown Mobility (Invest) 3.258 md/cp 4612.33 Buildup Start Drawdown Mobility (Final) 3.903 md/cp En Buildup Mud Pressure Before 5895.35 psia a Mud Pressure After 5897.02 psia 4612.13 1 • Mud After Temperature Before /After 144.61 DEGF / 144.81 DEGF Pretest Rate/Volume 1 c3 /s / 14.88 cc 4611.93 I II II I i 60s Slope (Final) 0.19 psia /m 187.5 221.6 255.7 289.8 323.9 Pressure Variance (Final) 2.27 psia Time (sec) 90 = MI MN OM — I — MI = — r MO • MB — MO IIIII Flow Regime Identification Plot : Test #23 Run 2 13936.56 ft (MD) 9959.52 ft (TVD) (Final) $chlumberger 1e +4, 2- 30B /ME -01 ✓1 Spherical Denvative T r • ❑ Radial Denvative 1r1 Il 4 ,ii •I!!'Ui!Ifl! l i . ,.., , -.► III > ∎NummummoI ∎aA. amoo � o Q 1111 d ___�iiii.. 11���� v r4,4 • 7._-,:.. ...., „Lik ... 1e-01 III w ill GII 1e -0- n le -0 1e+00 le +01 1e +02 Delta -Time (sec) 91 Pressure Vs Time Plot : Test #24 Run 2 13929.00 ft (MD) 9952.29 ft (TVD) Schlumberger 2- 30B /ME -01 I , o , c o o S . W O mr IF --V - • - - - = _ - (p LL (.9 _ 0 N o_ w N II ❑ d 0 < 0 2 1 1 O ■ a h 0 w r 0 J z w W co II n cc O W 0 C 0 E 10 F d 7 II g w 8 0 W d W 00 11 0 O Q 0 J w W 5' F F ✓ a a a In Z Q 7 W K a ❑ 11 a ( 0 F- 0 • U U 0 a U 0 7 ❑ 2 0 Z 3 W I Q S 11 11 11 11 O Cr) I O O o m0 N 0 ) O N � N ' 280 290 300 310 320 330 340 350 360 370 380 390 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Drawdown Start Invest. Packer Gauge TST675 Probe AQAP Buildup Start Invest Formation Pressure 4612.11 psia • End Buildup Invest Last Read (Invest) 4611.61 psia 0 Drawdown Start Last Read (Final) 4612.11 psia Drawdown A Buildup Start Drawdown Mobility (Invest) 0.968 and /c Y( ) P • End Buildup Mud Pressure Before 5886.51 psia Mud Pressure After 5884.59 psia Mud After Temperature Before /After 144.63 DEGF / 144.77 DEGF Pretest RateNolume 0.54 c3 /s / 2.41 cc 60s Slope (Final) 0.03 psia /m Pressure Variance (Final) 0.87 psia 92 IIMI MIN MIN 111•I MI IIIIIIII OM — I= • = MI N N MN — — E ism I M OM NM — — MI NM — UM — NM MN ME M — NM NM • Pressure Vs Time Plot : Test #24 Run 2 13929.00 ft (MD) 9952.29 ft (TVD) Schlumberger 2- 30B/ME -01 Investigation I 1 Final 1 o S oQ o o - O O h. o 0 m a /' R < . 0 2 a w u'1 - p w w O N j a it I— w Q W N W a W o: W M J a ° a v' -- > 0 2 a w F w Z F -, Q / W • ¢ o a a CO a F a • U Z • a N ' z Q LL • A I O M O O O A O O O O O N 7 NO N \ 100 200 300 400 4615.11 Detail Pressure Plot (Final) Time (sec) Test Type FPWD675 5 • M ud Before Packer TST675 Probe Drawdown Start Invest. 4613.11 I'' e , :, �� r ILL, , n " "" +' *� � r rri ,1 + II 1' I Gauge AQAP Buildup Start Invest Formation Pressure 4612.11 psia "Co- �� + x iJlla lyi Atilt Wk. ibI t • End Buildup Invest Last Read (Invest) 4611.61 psis x4611.11 Last Read (Final) 4612.11 psis Drawdown Start Drawdown Mobility (Invest) 0.954 md/cp z t A Buildup Start Drawdown Mobility (Final) 0.968 md/cp n 4609.11 2 . End Buildup Mud Pressure Before 5886.51 psia a_ 4., Mud Pressure After 5884.59 psia 4607.11 • Mud After Temperature Before /After 144.63 DEGF / 144.77 DEGF Pretest Rate/Volume 0.54 c3 /s / 2.41 cc 60s Slope (Final) 0.03 psia /m 4605.11 Pressure Variance (Final) 0.87 psis 293.19 322.35 351.51 380.68 409.84 Time (sec) 93 Flow Regime Identification Plot : Test #24 Run 2 13929.00 ft (MD) 9952.29 ft (TVD) (Final) Schlumberger 1 e +O ti 2-30B/ME-01 De ••■� m• ■ Spherical Deriva - - ■ - -_ - O Radial Derivative - - , - - - •71111 \ : • ULIII 1 -4 ,,,, \ • 1e +o ` , � �� t ' r ` i �� 111 �� :i � _1IuI III111 ■ t tf O l__ I._ ll,. '. _ _ - - -- '. .ten .� - . ' me r -. 41 11 ,1 l i���/ AM ' E MI . - 1 • • 2 11 rn 0) • F2 • ii 1e +02 _ ._ ❑ 0 0 1e +01 1e +00 1e +01 1e +02 Delta -Time (sec) 94 1 1 1 1 1 1 1 1 • • 1 1 1 1 I1 • MI NM ME INN NM I•1111 Ma 1111. IIIIII iMi NM OM NM Mil NM 111. MI IIIIII 111110 I= IIM Pressure Vs Time Plot : Test #25 Run 2 13852.26 ft (MD) 9878.86 ft (TVD) Schlumberger 2- 30B /ME -01 0 N N N m 0, 0, (0 LL d w .co t0 6 ❑ N a a n s i m < 0 2 a , i U w a �I Q n O 7 a w W 0 > • CO ❑ d CC 0 1- a ■ w w 0 o j w a w CO w 0 < 2 0) a - o w co - 0 O 1- N w a 0 > 0 - a 7 n w q Z F- J a 0 w • IH 0 II 11 o 0 o Z 0 LL o Z a O a LL o o l O m (0 o a 0 v v m m O N � N O N 100 200 300 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe X Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4785.59 psia • End Buildup Invest Last Read (Invest) 3890.31 psia Last Read (Final) 4785.59 psia Drawdown Start Q Drawdown Mobility (Invest) 0.591 md/cp 0 Buildup Start Drawdown Mobility (Final) 0.065 md/cp II End Buildup Mud Pressure Before 5842.45 psia Mud Pressure After 5837.9 psia • Mud After Temperature Before /After 144.36 DEGF / 144.72 DEGF Pretest Rate/Volume 0.42 c3 /s / 0.53 cc 60s Slope (Final) -1.29 psia /m Pressure Variance (Final) 0.78 psia 95 Pressure Vs Time Plot : Test #25 Run 2 13852.26 ft (MD) 9878.86 ft (TVD) Schlumber er 2- 30B/ME -01 9 In4stigaj Final I O O 00 0 O u� O o 0 0 O r 1... h. N LL / III - i W m m I n O. m ¢ O a m Q O f U Q W I Q W (- J D W w 0 N 7 0! X LL W I- d 0 w a w z w g3 1 J 7 W W - - ■ _ _ _ o> a a LL U) Z V F Q U Q W 0 O W O a N 0 1- a Q p 3 Z 3 in LL Q LL 7 .' ' M O O O O O O O O N N 0 N _ 100 200 300 400 Detail Pressure Plot (Final) Time (sec) Tool Type FPWD675 4793.59 - • Mud Before Test Type Type 2 - C Drawdown Start Invest. X Packer TST675 Probe 4789.59 Gauge AQAP m Buildup Start Invest Formation Pressure 4785.59 psia n4785.59 III End Buildup Inve Last Read (Invest) 3890.31 psia Last Read (Final) 4785.59 psia j 0 Drawdown Start Drawdown Mobility (Invest) 0.591 md/cp 4781.59 A Buildup Start Drawdown Mobility (Final) 0.065 md/cp End Buildup Mud Pressure Before 5842.39 psia a Mud Pressure After 5837.9 psia 4777.59 IN Mud After Temperature Before /After 144.36 DEGF / 144.72 DEGF Pretest Rate/Volume 0.42 c3 /s / 0.53 cc 60s Slope (Final) -1.29 psia /m 4773.59 (Final) Variance 136.06 190.25 244.44 298.63 352.81 407 ( ) 0.78 psia Time (sec) 96 MI I MI NM MN • MI • i• — — • • — • — — MN ■ ■ ■ ■ 1 ■ ■ • MI s — MN ■■ ■ NM • I= ■ ■■ Flow Regime Identification Plot : Test #25 Run 2 13852.26 ft (MD) 9878.86 ft (TVD) (Final) Schlumberger 1e +oF 2- 30B /ME -01 0 Spherical Denvative -. _ 1 E1 Radial Derivative - - -- 1 11111 le+0: 1111 1111111 ,. ■■■•••=1111■111111111■ME■■ll ■_■■_ •••■_■___ ■ ■ ■ ■■ \,\ I I O ___ ■■■- 111111..■ ■■■1 MIMI .11111 0 • •I•111 NM � .:;Ilia. i o 1 �. • .47) 11111111 1e +0' 11111111 A, __,_ - •,•• -. ,: I I 1 ■■ ■111 tit . r71 - �. p P2 MIEN El j .7 7, ,,, ,, LI:"" [ 4] , — -- 1�� fn .14 gil ■ ■...EA ■ ■■■1111 1e +02 le +00 le +01 1e +02 Delta -Time (sec) 97 Pressure Vs Time Plot : Test #26 Run 2 13846.50 ft (MD) 9873.35 ft (TVD) Schlumber er 2- 30B /ME -01 9 1 O 0 90 O O 0 o co W O V w),147 .: 5.) 'e Z) •.e) ) 1 lJ n n pe y0 .• • . . I. 4 5 C n .p . yl Z. .. e - ♦ 1 n 0 1 O W N .a 0 0 a . O y a O a n W d OC W W r a cr cr W W N 1 w a. W fx w N W W O> 0 , D < < —' U w a 1- o < W < 0 a LU a 0 0 I- a n 0 O 0 a 0 (/) LL < a LL C. m ■ 0 0 0 0 R gi O R 260 270 280 290 300 310 320 330 340 350 360 370 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 1 - B Packer TST675 Probe Q Drawdown Start Invest. Gauge AQAP 0 Buildup Start Invest Formation Pressure 4716.99 psia III End Buildup Invest Last Read (Invest) 4717.7 psia 0 Drawdown Start Last Read (Final) 4717.49 psia Drawdown Mobility (Invest) 5.891 md/cp 0 Buildup Start Drawdown Mobility (Final) 6.063 md/cp • End Buildup Mud Pressure Before 5811.94 psia Mud Pressure After 5806.58 psia Mud After Temperature Before /After 143.87 DEGF / 143.98 DEGF Pretest RateNolume 1 c3 /s / 7.56 cc 60s Slope (Final) 0.46 psia /m Pressure Variance (Final) 2.53 psia 98 • • MI MR 11111 I • • • • • • • MI • IIIII • 1111111 • MI NM ININ MI IIIIIII NM MN Mill II NM MI OM I IIIIIIII • • Pressure Vs Time Plot : Test #26 Run 2 13846.50 ft (MD) 9873.35 ft (TVD) Schlumberger 2- 30B/ME -01 1 Investigation [ 1 Final 0 N. 0 r- o 00 - o 00 N. 1 1 !6 11 U n W N y d O C'7 < • d C) Q U a u, < W , o S w W 2 a Y a W cn w w in w a w tY w w w Q a a F W Z H U �/ 0 Q Q C7 W Q O 0 a N o 1- a • a o Z U) LL Z a Q LL O N O (V o N 0 7 / N ON 100 200 300 400 (sec) Pressure Plot Final T ime Tool Type FPWD675 4720.49 I� �� ' � � ,�° I I' 11 I Ill Mud Before Drawdown Start Invest. Test Type Type 1 - B � Packer TST675 Probe 4718.49 r �) �I �'�I I 1 1! 1 11 h I ., I l l �� � III I B uildup Start Invest Gauge AQAP I� Formation Pressure 4716.99 psia x4716.49 � ' 111 End Buildup Invest Last Read (Invest) 4717.7 psia Last Read (Final) 4717.49 psia 0 D rawdown Start I 1 Drawdown Mobility (Invest) 5.891 md/cp g))4714.49 ,4714.49 I' I 1 1.Iii iii . I� ■�Ld 1 i . ■ � 1 1 it ii�� , 1 ill A Buildup Start Drawdown Mobility (Final) 6.063 md/cp a I, + ` +�II VIII Y a V f + I . End Buildup Mud Pressure Before 5811.94 psia a II 1, I I it � � I l It t hik II■ Mud Pressure After 5806.58 psia 4712.49 � L VI Mud After Temperature Before /After 143.87 DEGF / 143.98 DEGF I l 11111,111111111111•111111111E111111 60s Slope (Nol 1 46 /s / cc 4710.49 60s Slope a (FFinal) ) 0.46 psia/m 266.69 294.75 322.81 350.88 378.94 407 Pressure Variance (Final) 2.53 psia Time (sec) 99 Flow Regime Identification Plot : Test #26 Run 2 13846.50 ft (MD) 9873.35 ft (TVD) (Final) Schlumberger 1e +Oh 2- 30B /ME -o1 Radial Time Function Plot - . iii 1 _i - , - — - -- 6000 * Spherical Derivative 0 Radial Derivative - - J bill 1 4, III 1e +03 ' • 1111! • .49 �. e % , 5000— - -- • i u) 1 e +02 i t At k D eV D I 4 • m • d 1e +01 ' 0 • .5' CL ipit.i, "11 4 $ . ' IA d1 ' '1 IN 0 Y Y M 1e +0C l _} r� '' . 1e - 01 1e +00 1e +01 1e +02 Delta -Time (sec) Slope on Spherical 0.497 3000 Slope on Radial 0.030 2.1 2 0 Radial Time Last Buildup Pressure : 4717.49 psia Extrapolated Pressure : 4716.99 psia Horiz. Mobility Thickness : 13.753 md.ft/Cp Radial Slope : -6.41 100 IIIIIIIIIIIIIIIIIIIMIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIOIIIIMIIIMIIIIIIIIIIIIIIOIIIIIIIIMIIIIII 1111. I= 11111111 • ill NMI OM MI • • • • • =II • =I 1•111 • I= • Pressure Vs Time Plot: Test #27 Run 2 13841.13 ft (MD) 9868.21 ft (TVD) Schlumberger 2-30B/ME-01 - s --0 — V n . . . . . . . . . . . .. . . . - co a 0 o_ • < 0 O , < u) . C4 Lu • -,,, CC w 5 ti) j LCLC' s I — : 0- w I Cr Ili CO 6 ILI a_ w Ea w --. • 7 W O I— I— > 0 _, .- 0 f• ,.... < < u) Z D W ' b ° 6 W (' < 0 co 0 0 0 0 < 0 0 7 0 Z cn U- 6 .1 ol- 6 „ 6 I? - . EN EN Cs1 . ; 7 ; 0 0) 100 200 300 Time (sec) Tool Type FPWD675 R Mud Before Test Type Type 1 - B Packer TST675 Probe V Drawdown Start Gauge AQAP A Buildup Start Formation Pressure 4922.55 psia • End Buildup Last Read (Final) 4922.55 psia • Mud After Drawdown Mobility (Invest) 174.075 md/cp Drawdown Mobility (Final) 0.159 md/cp Mud Pressure Before 5788.89 psia Mud Pressure After 5784.94 psia Temperature Before/After 142.79 DEGF / 143.37 DEGF Pretest Rate/Volume 0.3 c3/s / 4.12 cc 60s Slope (Final) 9.18 psia/m Pressure Variance (Final) 0.55 psia 101 Pressure Vs Time Plot : Test #27 Run 2 13841.13 ft (MD) 9868.21 ft (TVD) Schlumber er 2- 30B/ME -01 9 o ° 80S r r r` N LL n W N m - - - - - • a a a - - U < l • 0 2' d W ! J E `O < 7 W a UJ w �' i d 7 0. ii O U F K 7 r� 4 _� O w z F- ❑ < ri W < 0 O ,� a co O O¢ t o 0 0 ❑ 0' ❑ 0 a Z c_ N LL < LL A O O O O _ OO O .. ... 100 200 300 400 4940 Detail Pressure Plot (Final) Time (sec) Tool Type FPWD675 Mud Before Test Type Type 1 - B Drawdown Start Packer TST675 Probe 4910 = 1. ' Gauge AQAP - " Buildup Start Formation Pressure 4922.55 psia 2 4880 End Buildup Last Read (Final) 4922.55 psia D r, Mud After Drawdown Mobility (Invest) 174.075 md/cp en 4850 �� r, Drawdown Mobility (Final) 0.159 md/cp Mud Pressure Before 5788.89 psia o f/ Mud Pressure After 5784.94 psia 4820 Temperature Before /After 142.79 DEGF / 143.37 DEGF r o Pretest Rate/Volume 0.3 c3 /s / 4.12 cc 4790' 60s Slope (Final) 9.18 psia /m 98.31 163.65 228.99 294.33 359.66 425 Pressure Variance (Final) 0.55 psia Time (sec) 102 • • • • • • • • • • • • • • • • • • • MO MO M 111. M MN INN MI — MI MI w I■I■ MI Flow Regime Identification Plot : Test #27 Run 2 13841.13 ft (MD) 9868.21 ft (TVD) (Final) Schlumberger 1 e +05 - 2-30B/ME-01 ' d Spherical Derivative " - - - - - ❑ Radial Derivative -- - " .■„ `\ ',tStS,:;: ?j; j�r, ', • • • II �, • 1 e +04 ,• _. -- - - -- ( !r/► N j _ r.„ --- �',lll ����tn��'I 2 ,� � ■ � ■ i, ... .. • i, 1e +0° O �� Ap_ e .r • 1.11 . ■memr•w'.m� ■__. ■_ ti L ``M r ... . .11 1111 hill Is L 1e +02 le +00 1e +01 1e+02 Delta -Time (sec) 103 Pressure Vs Time Plot : Test #28 Run 2 13841.89 ft (MD) 9868.94 ft (TVD) Schlumber er 2- 30B/ME -01 9 I fV O NO N N r N N 0) O T v v a ■ V W W n w m m o N a o a q ¢ O i W W n O W L ■ cc 2 F a 7 ∎1 1 J n 11 w n a a W u 0 a a D W N -J 0 4 W < a °- 2 D 0 � o Q O F y 0 1- G • < 0 i 3 1 E < W i 260 270 280 290 300 310 320 330 340 350 360 370 380 Time (sec) Tool Type FPWD675 In Mud Before Test Type Type 1 - B Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4748.06 psia • End Buildup Invest Last Read (Invest) 4747.05 psia Q Drawdown Start Last Read (Final) 4745.35 psia 0 Buildup Start Drawdown Mobility (Invest) 6.069 md/cp Drawdown Mobility (Final) 6.092 md/cp • End Buildup Mud Pressure Before 5784.08 psia Mud Pressure After 5782.87 psia Mud After Temperature Before /After 142.81 DEGF / 142.97 DEGF Pretest Rate/Volume 1 c3 /s / 7.44 cc 60s Slope (Final) 0.38 psia /m Pressure Variance (Final) 0.62 psia 104 • • I= NM — • 11111 = • 11111 • I= — r • = — • I= • • all — • S — • • — OM N • MI • r • MN • Pressure Vs Time Plot : Test #28 Run 2 13841.89 ft (MD) 9868.94 ft (TVD) Schlumberger 2- 30B /ME -01 Investigation I I Final 8 8 80 8 o: O O n r- r /I S/ _ .. .. III m 111 a w m m O a n • a • ' 0 a U Q (1)1 Q w J w w • N 0 a CC a w w 2 D w r ------V r giff€93943€999699 rfile ifg29399seeeeeeGe ' e-e-943-11 7 a • ,2 W W CO Q I- Q I- Q O a J U O O 7 p , a A z c_ u) - Q , O O O O O / O N r NO N 100 200 300 400 Detail Pressure Plot (Final Time (sec) Tool Type FPWD675 4748.35 • Mud Before Test Type Type 1 - B Packer TST675 Probe 1 X Drawdown Start Invest. Gauge AQAP 4746.35 ° "' �' �r ^�'' Buildup Start Invest Formation Pressure 4748.06 psia m L ast Read (Invest) l 4744. 35 '� End Bu ildup Invest ( ) 4747.05 sia p Last Read (Final) 4745.35 psis 3 � Build up I Drawdown St art 11 St Drawdown Mobility (Invest) 6.069 md/cp v`�,4742 Drawdown Mobility (Final) 6.092 md/cp 9.2 �, • End Buil Mud Pressure Before 5784.08 psia n r 1 Mud Pressure After 5782.87 psia 4740.35 • Mud After Temperature Before /After 142.81 DEGF / 142.97 DEGF Pretest Rate/Volume 1 c3 /s / 7.44 cc 60s Slope (Final) 0.38 psia /m 4738.35 274.56 301.05 327.54 354.03 380.51 Pressure Variance (Final) 0.62 psia Time (sec) 105 Flow Regime Identification Plot : Test #28 Run 2 13841.89 ft (MD) 9868.94 ft (TVD) (Final) Schlumherger 1e +04 2- 30B /ME -01 Spherical Time Function Plot : 1 O Spherical Derivative 6000 0 Radial Derivative - - - 1 col e+0:: o I . •� 1 4r, I ll 1e +02 UII O 2 5000 +_ N rn 2 22 1e +01 1e +00 le +01 = 02 ' Delta -Time (sec) Slope on Spherical -0.046 Slope on Radial -0.473 3998 n 3.6 2.000 0 Spherical Time, 1 /sgrt(sec) Last Buildup Pressure : 4745.35 psia Extrapolated Pressure : 4748.06 psia Buildup Mobility : 1.51 and /cp Spherical Slope : - 205.19 106 MN MI IIIIII • NM NM • • • I= • MI • MN I= IIIIII 111111 • N — III II III On MB IM — — UM — IM r — II INN Pressure Vs Time Plot : Test #29 Run 2 13823.83 ft (MD) 9851.67 ft (TVD) Schlumberger 2- 30B /ME -01 I n - ' . � N. e v e m .. w m m O _ _ a n n c7 < 0 Q U Q 'nI Q W -J 2 W w > (I) j a ,' 'E V,3 1- r w g o_ a 0 CC CO a J W 2, J W O> Q i ¢ a F 2 z i2 U w q 0 o a 0 1- F 0 0 0 d a 0 0 D 0 0 3 D w 0 Z Q PL O M 0 00 00 O VQ 3 300 310 320 330 340 350 360 370 380 390 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 1 - B Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4689.09 psia II End Buildup Invest Last Read (Invest) 4689.5 psia Last Read (Final) 4688.35 psia Drawdown Start Q Drawdown Mobility (Invest) 30.399 md/cp 0 Buildup Start Drawdown Mobility (Final) 25.609 md/cp II End Buildup Mud Pressure Before 5758.6 psia Mud Pressure After 5756.26 psia • Mud After Temperature Before /After 142.61 DEGF / 142.63 DEGF Pretest Rate/Volume 1 c3 /s / 7.47 cc 60s Slope (Final) 0.13 psia /m Pressure Variance (Final) 0.9 psia 107 Pressure Vs Time Plot : Test #29 Run 2 13823.83 ft (MD) 9851.67 ft (TVD) Schiumber er 2-30B/ME-01 9 Investigation I I Final 8 0 80 O N 0 O O O O O t• � r Ti \s is LL Q w i? \ 0 ° o a g ¢ O a - Q N c4 41111111111 w J w w a j K w a w ~ Q a D w a w w w j Q Q. a a w O 0 a a F 0 w Z H p Q K Q ❑ 0 CI- N 0 F a � a 00 0 z 0 N LL LL ! 0 0o -117 .- i o a 0 o 0 / \ 0 v 100 200 300 400 4691.35 Detail Pressure Plot (Final) Time (sec) Tool Type FPWD675 III Mud Before Test Type Type 1 - B Drawdown Start Invest. Packer TST675 Probe 4689.35 rim • 1 t i ; g Gauge AQAP @ / Buildup Start Invest Formation Pressure 4689.09 psia II III End Buildup Invest I • Last Read (Invest) 4689.5 psia x4687.35 Last Read (Final) 4688.35 psia V Drawdown Start Drawdown Mobility (Invest) 30.399 md/cp 4685.35 ; • A Buildup Start Drawdown Mobility (Final) 25.609 md/cp a` 0 • End Buildup Mud Pressure Before 5758.6 psia 0 Mud Pressure After 5756.26 psia 4683.35 11 • Mud After Temperature Before /After 142.61 DEGF / 142.63 DEGF 0 Pretest Rate/Volume 1 c3 /s / 7.47 cc 4681.35 60s Slope (Final) 0.13 psia /m 305.13 325.7 346.28 366.85 387.43 408 Pressure Variance (Final) 0.9 psia Time (sec) 108 • MI .1111 MI MN 11111 N I• • MIN MI II NM • I•1 UNII .111 In • MS — M MI 1 E N M en N I NM 11.1 IIMM • INN Flow Regime Identification Plot : Test #29 Run 2 13823.83 ft (MD) 9851.67 ft (TVD) (Final) Schlumberger 1e +o 2- 30B/ME -01 Spherical Time Function Plot : —■ '- 01 __ ∎ ∎ =oo. 4800 rivative = =•Unl _ME=M•Unl � ���. Rad D Dative =MEM ll ■■••••11 ❑ Radial Deriv 111111111 - ■„"'1I Jiii•uuiiuii•uiiunii IIh1IIIIIlIIII•IIIIIIII (64700 (7) eginall.1101 1e+0 ■= mi. ■■■r on n o nem 0_ ■r MI ∎MM ■••u11 ∎MMu■.u11 = I co co 2 EL 4507 n co 3.6 2.000 0 as LastBUildupPressure 4 g pheP58aI Tlme, 1 /sql f(sec) 1 e +01 EArapolated Pressure 4689.24 psia ❑ � ��� I' i ===2 Buildup Mobility 19.06 md/cp Nimmmwi,. - . ,1- 1.Mr∎MEME I1- Spherical Slope -4.54 7 __. •r 1. ' ■W L': `\II■ •11 N =M■■11 :- • v 111111► '1∎ a. U11 co a_ U111141 ~ III IIIII � �o' � "JII Radial Time Function Plot le +01 IIIIIIIIl•d 4800 �r:� - mom.. -- um ■M11111•\III ■■•111•1111=LI 74111M11111LJMME MINI•■■uuIIMINIIIIIIM■■uul ' •1M - 711UuuI IIIIIIIIIIIII Lr 'III n 1 e -01 ∎ ∎■■∎ ∎. .■■ � ∎ ∎ ∎ =..■. ∎ — ■∎ ■=..■. >� 4600 ■■=w■■■nn..■. �. - 7•.01 - __ .. •=MMEMO1 i■MINE=•UU..1M■∎\M11••••1 (7 d 0 1 e -0 le +00 le +01 Slope on Spherical -0.072 4400 0 Delta -Time (sec) Slope on Radial -0.480 2.1 2 Slope on Spherical 0.458 Radial Time Slope on Radial 0.018 Last Buildup Pressure : 4688.35 psia Extrapolated Pressure : 4689.09 psia lioriz. Mobility Thickness : 144.034 md.ft/Cp Radial Slope : -.61 109 Pressure Vs Time Plot : Test #30 Run 2 13819.76 ft (MD) 9847.77 ft (TVD) Schlumber er 2- 30B/ME -01 g to 6 0 in to r n n a u m m a e a a UI ! ' I Q a w O 0 ¢ a- U LL Z 1 J O < Q ❑ O a • 0) 0 a a 0 z 3 N U ✓ o v N O N N O cr dO O 210 220 230 240 250 260 270 280 290 300 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4689.05 psia • End Buildup Invest Last Read (Invest) 4687.72 psia V Drawdown Start Last Read (Final) 4689.05 psia Drawdown Mobility (Invest) 53.012 md/cp 0 Buildup Start Drawdown Mobility (Final) 32.383 md/cp • End Buildup Mud Pressure Before 5753.76 psia Mud Pressure After 5753.87 psia Mud After Temperature Before /After 142.39 DEGF / 142.43 DEGF Pretest RateNolume 1.01 c3 /s / 7.36 cc 60s Slope (Final) 4.28E -03 psia /m Pressure Variance (Final) 0.53 psia 110 W111 1111 11111 M NM NM 11111 N NM NM I OM M • — — — — — — — — — — • i — — r r Pressure Vs Time Plot : Test #30 Run 2 13819.76 ft (MD) 9847.77 ft (TVD) Schiumberger 2- 30B/ME -01 Investigation I 1 Final 1 O 3 80 3 o - 0 0 or o lU i -(1,-5' No W m m a . i a 0 2 Q O ¢ W a LL o L w W ... _i r r .r-- .. ,. a u) a D w a w rY w 2 J a a n a ❑ W N J O • U F .- 7 ¢ a a r W Z F J ¢ w a ❑ O a • N a ,- a a o z 3 w LL as a LL 7 O M O O O O O O O O7 °O. 100 200 300 400 Detail Pressure Plot (Final) Time (sec) Tool Type FPWD675 4692.05 IN Mud Before Test Type Type 2 - C Packer TST675 Probe X Drawdown Start Invest. Gauge AQAP 4690.05 0 Buildup Start Invest Formation Pressure 4689.05 psia 0 Ill End Buildup Invest Last Read (Invest) 4687.72 psia 24688.05 a Last Read (Final) 4689.05 psia D rawdown Start 2 ;. 0 Drawdown Mobility (Invest) 53.012 md/cp 24686.05 I 0 Buildup Start Drawdown Mobility (Final) 32.383 md/cp 12 End Buildup Mud Pressure Before 5753.82 psia d V Mud Pressure After 5753.87 psia 4684.05 — III Mud After Temperature Before /After 142.39 DEGF / 142.43 DEGF Pretest Rate/Volume 1.01 c3 /s / 7.36 cc 60s Slope (Final) 4.28E -03 psia /m 4682.05 Pressure Variance (Final) 0.53 psia 211.94 251.35 290.76 330.18 369.59 Time (sec) 111 Flow Regime Identification Plot : Test #30 Run 2 13819.76 ft (MD) 9847.77 ft (TVD) (Final) Schlumberger e +oa 2-30B/ME-01 l Spherical Derivative -- 0 Radial Derivative -- - { 1e +03 1e +02 MIN cn M l ._ I 111111 1e +01 — e . • IA 1e +OC l ■i :�i «1 - i I Illii _ 1 e -01 0 1e -02 1e +00 1e +01 1e +02 Delta -Time (sec) 1 12 INN MON 10.1 1.11 MIN INN MO MO 11. 1.0 I MO ON OIN IIIIIIIII NM IIIIIIII ala Min NM 111. EN MB MS MI 111111 MI MN MIN IIIII1 111. Mi MN Pressure Vs Time Plot : Test #31 Run 2 13812.65 ft (MD) 9840.97 ft (TVD) Schiumberger 2- 30B/ME -01 N - i I n o rn rn N- N- n e e v • V - it o u y 0 0 m ti 0 o_ W m m 1) Q N g n u m < 0 a u 'Cr?' a rn O - - L11 ? 11 J w W O (/) 7 a d' 11 CI N 1- 7 w Q w g3 o W a W K w J a (7n a y 11 O U r cf j < : < a , u (n Z 7 -' a Lil a o d a O z Z N LL Z a a , 1 0 m N N N N N co 0 c co 210 220 230 240 250 260 270 280 290 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4687.58 psia MI End Buildup Invest Last Read (Invest) 4687.63 psia Last Read (Final) 4687.58 psia Drawdown Start V Drawdown Mobility (Invest) 4.581 md/cp 0 Buildup Start Drawdown Mobility (Final) 4.167 md/cp El End Buildup Mud Pressure Before 5776.86 psia Mud Pressure After 5778.9 psia • Mud After Temperature Before /After 142.07 DEGF / 142.36 DEGF Pretest Rate/Volume 1 c3 /s / 8.04 cc 60s Slope (Final) -.05 psia /m Pressure Variance (Final) 0.48 psia 113 Pressure Vs Time Plot : Test #31 Run 2 13812.65 ft (MD) 9840.97 ft (TVD) Schiumber er 2- 30B /ME -01 9 1 Investigation I I Final 0 0 0 0 0 - 0 0 r` n n illis l... IIIII� - LO m a n CO • d 2 Q U wwI Q W o w W n 7 n- K d CO g a 7 W a W Cr w 1 o • r i t a [ > U Q Q LL I- Y :: .. U _ 7 J Q 7 7 U 0 0 ° u z c , LL a LL A O N O O O / \ O N O NO N i 100 200 300 400 II Detail Pressure Plot Final Time (sec) Tool Type FPWD675 4687.88 MU ^ 1 IF 1.1 f I, I 7 I II I I I f I I1 I L' Mud Before Packer Type TST675 Probe • 4687.68 11 I I f I II li I I 111. v Drawdown Start Invest. Gauge AQAP m III; Buildup Start Invest Formation Pressure 4687.58 psia 04687.48 ! I , I I d III End Buildup Invest Last Read (Invest) 4687.63 psia Last Read (Final) 4687.58 psia II V Drawdown Start MI Drawdown Mobility (Invest) 4.581 and /cp 0 B uildup Start D rawdown Mobility (Final) 4.167 md/cp ( ) P • End Buildup N I Mud Pressure Before 5776.86 psia a Mud Pressure After 5778.9 psia 4687.08 Mud After Temperature Before /After 142.07 DEGF / 142.36 DEGF 11 1 Pretest RateNolume 1 c3 /s / 8.04 cc 4686.88 ! 11 1 I. !8 Ii I II'I 1, . 11 1 11,1 11 1 II 1 60s Slope (Final) -.05 psia /m 209.63 249.3 288.98 328.65 368.33 Pressure Variance (Final) 0.48 psia Time (sec) 114 • — allii MIII OM 1.0 Mili all OIN NS INM NM aln I• r • MI MI MI - - - - - - - - - - - - i - r - - - - Flow Regime Identification Plot : Test #31 Run 2 13812.65 ft (MD) 9840.97 ft (TVD) (Final) Schlumberger 1 e +oa 2-30B/ME-01 0 Spherical Derivative -- - -- -- - - - - - - D Radial Derivative -; I I - - + 1 e +0C, ,s. MMMIMp III ii / , •% INI J to 1 e +02 1• *E.) .1 .1 N ,, ■ & EL 1e +01 ,r in, r- m.=1■11111/4110111111■4111.1• , �l , El 1 ❑ I;I 1e +OC ❑ y ' i r GA li II,- ■ le-01 1e +00 1e +01 1e +02 Delta -Time (sec) 115 Pressure Vs Time Plot : Test #32 Run 2 13803.82 ft (MD) 9832.52 ft (TVD) Schlumber er 2- 30B /ME -01 g I a0 S WG Q '- r r t0 , U n r r v e v 0 0 0 A L(' 0. W c. • a 0 a • N 0 O • o < 0 2 0 O Q m w J Q: w W O N j d • a W Q . 0 2 w w a w Cr a 7 Q 2 v) h F- < a a- u) Z 7 O W Q O a u) 0 2 a 7 0 O Z d O Z LL 0 L A 27 M C7 r r Lel O N o a 4 '0 a 210 220 230 240 250 260 270 280 290 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe 0 Drawdown Start Invest. Gauge AQAP A Buildup Start Invest Formation Pressure 4680.71 psia • End Buildup Invest Last Read (Invest) 4679.96 psia 0 Drawdown Start Last Read (Final) 4680.71 psia Drawdown Mobility (Invest) 15.38 md/cp A Buildup Start Drawdown Mobility (Final) 13.053 md/cp • End Buildup Mud Pressure Before 5784.74 psia III Mud Pressure After 5783.7 psia Mud After Temperature Before /After 142.34 DEGF / 142.5 DEGF Pretest Rate/Volume 1 c3 /s / 7.33 cc 60s Slope (Final) 0.09 psia /m Pressure Variance (Final) 0.87 psia 1 16 — — • — — — • — r — — — — — • — • MN an MN UM I En — NM MB an — W — — — MI w— NM Pressure Vs Time Plot : Test #32 Run 2 13803.82 ft (MD) 9832.52 ft (TVD) Schlumberger 2- 30B/ME -01 Inv estigatio n Final O ' S OO O O r O O Pli LL / --9-- 0 m m y � n n Q , c,, ¢ ¢ U' 2 Q o ¢ 0 O w' - w w O 2 j a a cn w w v w a w a w D a a m a w ^' eseefee—ER II T I _ O r N Z 7 ' Q w ¢ U . C7 w ¢ O a a m O r ¢ Z m LL a LL O / co O O O / LL O O N N O N NQ N 100 200 300 400 Detail Pressure Plot Final Time (sec) Tool Type FPWD675 4681.01 ,�� I I 1 1 li P a c t e e T e 2- C Mud Before Type Type Packer TST675 Probe 4680.81 Drawdown Start Invest. Gauge AQAP _ ( I 1 L Buildup Start Invest Formation Pressure 4680.71 psia �I n4680.61 all End Buildup Invest Last Read (Invest) 4679.96 psia Last Read (Final) 4680.71 psia 112 Drawdown Start Mobility Mobili ty (Invest) 15.38 and /cp y A Buildup Start Drawdown Mobility (Final) 13.053 and /cp 4680.41 III End Buildup Mud Pressure Before 5784.74 psia a Mud After Mud Pressure After 5783.7 psia 4680.21 Temperature Before /After 142.34 DEGF / 142.5 DEGF Pretest RateNolume 1 c3 /s / 7.33 cc 4680.01 111 I 1 60s Slope (Final) 0.09 psia /m 218.06 251.05 284.04 317.03 350.01 Pressure Variance (Final) 0.87 psia Time (sec) 117 Flow Regime Identification Plot : Test #32 Run 2 13803.82 ft (MD) 9832.52 ft (TVD) (Final) Schlumberger 1 e +O 2-30B/ME-01 Spherical Derivative - _ -- - - - - – 0 Radial Derivative te k le+OZ. i 1e +OZ. , co - � t d m 1 I 1 C j p 1e +01 . ■ d IiI 0 ',.'. ti to +OC ^ ♦ iii... -: , . , 4■7 IIM • f le-01 ❑ I 1 ❑ rt ,– 1e 02 le +00 1e +01 le +02 Delta -Time (sec) 118 NM • • — NM — • — — — • — — — — — r aIN Pressure Vs Time Plot : Test #33 Run 2 13794.69 ft (MD) 9823.79 ft (TVD) Schlumberger 2- 30B/ME -01 I m O m o, r CO <D . _ N- n n - _ - t. ii 0 to 11 N 0 IC 11 o_ w m m u ❑ a . 0 o f ¢ O a_ U a 0 2 u' o - w /n Q o O j a CC 9 °-. 1- m Q w w 2 /1 w cr w - • j a_ 7 CC g., 0 - N o _ W ,, o • < < n I- uj Z ❑ ' Q 1- Q 0 ❑ 0 - - W Q ❑ O a 1(7) d I- C 4 0 3 Z • d Q LL . I 0 c LL. N to O O O O O M M 0 (7 250 260 270 280 290 300 310 320 330 340 350 360 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4692.01 psia • End Buildup Invest Last Read (Invest) 4693.07 psia Last Read (Final) 4691.38 psia Drawdown Start Drawdown Mobility (Invest) 3.195 and /cp A Buildup Start Drawdown Mobility (Final) 3.641 and /cp • End Buildup Mud Pressure Before 5764.05 psia Mud Pressure After 5761.31 psia • Mud After Temperature Before /After 142.32 DEGF / 142.57 DEGF Pretest RateNolume 1 c3 /s / 11.6 cc 60s Slope (Final) 0.01 psia /m Pressure Variance (Final) 1.12 psia 1 19 Pressure Vs Time Plot : Test #33 Run 2 13794.69 ft (MD) 9823.79 ft (TVD) Schiumber er 2- 30B /ME -01 Investigation 1 1 Final 0 0 80 3 o O O n n n L NM 7 ( a p 1 10 n n c; < • a 2 a o Q N d w N w w > N D r r Q 1 - .- W a D w a w r w K a J W 330990-11V f O Q Q d U W Z F JO Q ( / r.---S7 1 1 . I- Q c, d a N F a a Q 0 ', o a Z , Z a Q LL V A O M O O O / N O N N O N , NO ry 100 200 300 400 4694.38 I Detail Pressure Plot Final II � Time (sec) Tool Type FPWD675 �� _M Mr I � �� r ��f�� ' ■ Mud ore Packer TST675 Probe DrawdoBef Test Type Type 2 C wn Start I nvest. Gauge Formation Pressure AQAP 4692.38 Buildu Start Invest o r maton ressure 4692.01 p sia `� LI �� �I� . l ` I i u d I i ii ` I ` {� p N 1 . � �l � tW' ilk 1 � �`��4IJ I i� �l'� � l i I � IW IYJ�Jifll /i 1 :� l I �I AII • End Buildup Inves Last Read (Invest) 4693.07 psia 4690.38 � 4691.38 psia Drawdown start Drawdown Mobility (Invest) 3.195 md/cp 4688.38 1.11111iiiillillidl Last Read (Final) Buildup Start Drawdown Mobility (Final) 3.641 and /cp End Buildup Mud Pressure Before 5764.05 psia a Mud Pressure After 5761.31 psia 4686.38 E ll s M , III Mud After Temperature Before/After 142.32 DEGF / 142.57 DEGF '� Pretest Rate/Volume 1 c3 /s / 11.6 cc 60s Slope (Final) 0.01 psia /m 4684.38 Pressure Variance (Final) 1.12 psia 257.13 286.7 316.28 345.85 375.43 405 Time (sec) 120 • • • MN MS 11.1 01111 MS MI MI NIIII NM 11111 OM 111. MII 11111 On Flow Regime Identification Plot : Test #33 Run 2 13794.69 ft (MD) 9823.79 ft (TVD) (Final) Schlumberger 1e+04- 2- 30B /ME -01 Spherical Time Function Plot : d Spherical Derivative - Ntari ∎ ∎ ∎• 6000 ❑ Radial Derivative 11111111 111 rs M =.11 ME == •I. 8 1 e +03 ••‘__. 111 WI; �1 / / ll 111 /, CO N 1e +02 ■ r__ / I 5000 N i.l I 7 N e - `\ d 1e+01 ,. Ir'••d : - ti - m 7 ti ' r J ❑ 2/ ■ ler 1 e +OC - — r.7„ y y � _ • IGii 1 e -01 1e +00 1e +01 1e +02 Delta-Time (sec) Slope on Spherical -0.038 3458 3 7 n ( ) Slope on Radial -0.549 2.000 0 Spherical Time, 1 /sqrt(sec) Last Buildup Pressure : 4691.38 psia Extrapolated Pressure : 4692.01 psia Buildup Mobility : 15.02 and /cp Spherical Slope : -6.5 121 Pressure Vs Time Plot : Test #34 Run 2 13850.04 ft (MD) 9876.74 ft (TVD) Schlumber er 2- 30B/ME -01 9 I O 0 000 i - - - 0- 0- < - C. N 0 0 - - - - - - C. = C - • 0- ,1 1, ,l I m 0 0 o_ u m m ,,1 a o 0. .n u M < 0 2 Q 0 ( _7 Q (:)1 O +I LL o w w 4 1- N d 7 11 a L 1 w 2 0 0 a u CC 0 0 - a 7 cC 11 N a N o U F j II < Q a U u W QQ Z H ,, Q o w K < o 0 11 0 a ( = U II N 0 a r Q 11 - • a 0 o o j o O a, Z m U 1 Z 11 a LL 11 1 11 11 11 11 1 M 0 0 0 N (0 to cn O 0, 0, N N N Ai 0 N r N� N 230 240 250 260 270 280 290 300 310 320 330 340 350 Time (sec) Tool Type FPWD675 • Mud Before Test Type Type 2 - C X Packer TST675 Probe Drawdown Start Invest. Gauge AQAP Buildup Start Invest Formation Pressure 4766.03 psia • End Buildup Invest Last Read (Invest) 4770.45 psia Last Read (Final) 4766.03 psia 0 Drawdown Start Drawdown Mobility (Invest) 0.825 md/cp A Buildup Start Drawdown Mobility (Final) 0.972 md/cp End Buildup Mud Pressure Before 5794.77 psia II Mud Pressure After 5793.36 psia Mud After Temperature Before /After 142.54 DEGF / 142.74 DEGF Pretest RateNolume 0.49 c3 /s / 3.12 cc 60s Slope (Final) -.46 psia /m Pressure Variance (Final) 0.4 psia 122 = • = M NM MI NM OM NM NM IIIM • MI MI NM UM III. On NM Pressure Vs Time Plot : Test #34 Run 2 13850.04 ft (MD) 9876.74 ft (TVD) Schlumberger 2- 30B/ME -01 I Investigation 1 I Final I o o o0o o u> o O O 0 0 n r r , W • �, l ) . al a W O a Q / v ¢ O a / < d 2 ¢ U ¢ n Q W N K W W O 2 3 a w a d rn 1 Q - w - c K W co W a W W 7 w a - < ¢ a I- W Z I- J ¢ ❑ ❑ V W 1 Q CJ t d i2 a . d r Q I J ¢ O ❑ _ wV3 O ED O a Z 3 ai LL ¢ a X o 0 m ° o o 0 0 0 0 A \ n n u I N. 100 200 300 400 4769.03 Detail Pressure Plot (Final) Time (sec) Tool Type FPWD675 Mud Before Test Type Type 2 - C Packer TST675 Probe Drawdown Start Invest. Gauge AQAP 4767.03 IIA pp rt,nwr p 'MI n+�1nrp1 rn r, ,wpr }n rn'WIPrlirlrl'19I R �,,�,�,,'��` I I! Buildup Start Invest Formation Pressure 4766.03 psia n ,,:r :uiiiitiiIl ki�1�111I i II Iiiiiiiiiiiii • End Buildup Invest Last Read (Invest) 4770.45 psis n4765.03 Last Read (Final) 4766.03 psis Start t � V Drawdown Drawdown Mobility (Invest) 0.825 md/cp 2 4763.03 Q 1 A Buildup Start Drawdown Mobility (Final) 0.972 md/cp I I • End Buildup Mud Pressure Before 5794.77 psia o_ Mud Pressure After 5793.36 psia 4761.03 " Mud After Temperature Before /After 142.54 DEGF / 142.74 DEGF Pretest RateNolume 0.49 c3 /s / 3.12 cc • 60s Slope (Final) -.46 psia /m 4759.03 Pressure Variance (Final) 0.4 psia 235.75 269 302.25 335.5 368.75 402 Time (sec) 123 Flow Regime Identification Plot : Test #34 Run 2 13850.04 ft (MD) 9876.74 ft (TVD) (Final) Schlumberger 1 e +oa 2-30B/ME-01 O Spherical Denvative ID Radial Derivative - _ ,_ _ Y_ _ % • . "e/ III O `` \ \\ \ \ \\ I 1e +0 ❑ 1111111IIIIIIlltt.. I.. L.a r, ♦ . IIIIIIEMEME '. ♦ MIEN i-. • ri cn p 1e +02 • N 0 �• v ❑ e En 0 2 a ❑ 0 • ■ III! Al ■ 1e +01 ❑ 0 rth El 1e +OG 1e +00 1e +01 1e +02 Delta -Time (sec) 124 NM — • I= — — • — MN — MN MB — • • • — • P I HALLIBURTON Sperry Drilling Services I ppl ► 0 • END 02- 30B /ME 01 I END OF WELL REPORT k . n:44. ) V 1 � , tom � _ �._-..«« -. _ ,i i. - !._ „, Et <- - • 7" — '-.* - .. ' I_ .1,.. [ , I I I Surface Data Logging Services I I TABLE OF CONTENTS 1. General Information 2. Daily Summary t 3. Morning Report 1 4. Bit Record 5. Mud Reports 6. Show Report ' 7. Days vs. Depth 8. Sample Report ' 9. Calibration Daily 1 10. CD Data 11. Formation Evaluation Logs (MD) 12. Formation Evaluation Logs (TVD) 1 13. Gas Ratio Logs (1:600 MD & TVD) 14. Gas Ratio Logs (1:240 MD & TVD) 15. Gas Ratio Logs ( 1:1000 MD & TVD) 1 16. Drilling Evaluation Logs II I I I HALLIBURTON Sperry Drilling Services 1 I 1 I I by 1 0 I GENERAL WELL INFORMATION I Company: B.P. Alaska I Rig: Doyon 14 Well: END 2- 30/B -01 I Field: Prudhoe Bay Borough: North Slope State: Alaska I Country: United States API Number: 50- 209 - 21609 -01 Sperry -Sun Job Number: AK -AM- 0006247187 I Sidetrack Date: 21 Feb, 2009 Total Depth Date: 07 Mar, 2009 09:30 hrs Total Depth: 14207' MD I Longitude: Latitude: 148° 14' 37.02" N 70° 14' 20.87" W Drill Floor Elevation: 28.50' above MSL I Ground Elevation: 39.50' above MSL SDL Engineers: Eugene Payne I Steven Jenkins Wayne Hermanson Company Geologist: Donna Messer I Curt Goddard SSDS Unit Number: 110 I This well is a sidetrack from original hole 2- 30A/E1 -02 accomplished by milling a window between 5818.8' to 5859.0'. The well was designed to intersect the Ivishak/Sag I production zones in a new fault block. I HALLIBURTON I Sperry Drilling Services I I DAILY SUMMARY BP END 2- 30B /ME -01 2.. DAILY SUMMARY 24 Feb 2009: Nipple up BOP stack. Retrieve storm packer. Run in hole and tag bridge plug at 5839'. Displace well to 9.1 ppg mud. Pull out of hole. Make up whipstock assembly. Trip in hole to 5,839' and mistakenly set whipstock 180° off center due to pipe talley discrepancy, therefore pull out of hole with whipstock assembly. 25 Feb 2009: Make up new starter mill and whipstock. Run in hole, orient and set whipstock. Mill window from 5,818.8' to 5,859'. Ream trough window and pump HiVis sweeps to clear iron shavings. 1 26 Feb 2009: Clear rig floor and test BOP's. Make up new bottom hole assembly. Note: Had false H alarm due to sensor malfunction and evacuated rig personnel to Endicotte camp. Pick up 5" drill pipe and run in hole. Run "Mad Pass" log from 5,753' to 5,835'. Ream undergauge hole from 5,835' to 5,859'. Directional drill 8 -1/2" hole from 5,859' to 1 6,164'. 27 Feb 2009: ' Directional drill 8 -1/2" hole from 6,164' to 8,608'. Background gas ranged from 80 to 196 units with a sharp peak of 6,072 units between 6,720 to 6,763' — coal gas. 28 Feb 2009: Directional drill 8 -1/2" hole from 8,608' to 10,672'. Average background gas ranged from 79 to 367 units with no significant gas peaks. 01 Mar 2009: Directional drill 8-1/2" hole from 10,672' to 11,533'. Background gas ranged from 20 to 130 units, averaging 50 units. Drilling was temporarly stopped while waiting on weather. ' 02 Mar 2009: Wait on weather until 08:30 hours. Directional drill 8 -1/2" hole from 11,533' to 12,146'. Note: Added Lube 776 and Lo Torq to improve hole lubricity for sliding and pumped HiVis sweeps as required. Gas values were lower due to 1 slower rate of penetration, ranging from 39 to 94 units, with no significant gas peaks. 03 Mar 2009: Directional drill 8 -1/2" hole from 12,146' to 12,559'. Circulate bottoms up and wiper trip 16 stands to 11,052'. Directional drill 8 -1/2" hole from 12,559' to 12,612'. Displace mud system to 10.5 ppg LSND. Directional drill 8-1/2" hole from 12,612' to 12,696'. 04 Mar 2009: Directional drill 8-1/2" hole from 12,696' to 13, 173'. Average background gas ranged from 15 to 103 units with no significant gas peaks. 05 Mar 2009: Directional drill 8 -1/2" hole from 13, 173' to 13, 690'. Average background gas ranged from 22 to 1,171 units with no sharp peaks, while moderate gas levels were encountered throughout the tuffaceous shales. Complete MWD Mad Pass from 13, 690' to 13, 567'. Pull out of hole from 13, 567' to 5, 564'. 06 Mar 2009: Pull out of hole and lay down MWD tools. Pick up and run in hole with new 8 -1/2" BHA to 13, 690' MD. Mad Pass with MWD from 13, 600' to 13828'. Drill 8 -1/2" hole from 13, 690' to 13, 828'. Average background gas ranged from 167 to 6538 units with a significant gas peak seen in the Sag formation. 1 1 1 DAILY SUMMARY BP END 2- 30B/ME -01 r 07 Mar 2009: Drill 8 -1/2" hole from 13, 828' to TD at 14, 207. Average background gas ranged from 143 to 2,898 units with 2 significant gas peaks seen in the Ivishak formation. Take Geo Tap readings using MWD at pre determeined depths from 13, 870' from 13, 826'. 08 Mar 2009: Finish up downhole logging program. Pull out of hole for short trip from 14, 207' to 11, 661'. Run in hole to 14, 114'. Establish circulation with 194 units of short trip gas seen on bottoms up. Spot G -Seal pill at 13, 830' and pull out of hole to surface. 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 2 I t �r Customer: B.P.X Alaska Report #: 1 Well: 2-30b-ME-01 Date: 27/02/2008 Sperry Oriiiing s®rvio @s Area: Endicott 4 :00 Depth: 6549 I Progress 24 hrs: 350 Rig: Doyon -14 Rig Activity: Drilling Mudlogger's Morning Report Job No.: AK -AM- 0006247187 Report For: Drstribution List I Daily Cost: $2,791 Cumulative Cost: $18,569 ROP &Gas: Current 24 hr Avg 24 hr Max Max @ ft Pump & Flow Data: I R.O.P. ft/hr 200.0 75.0 275.0 6525 Flow in • •m 548 SPP •si 1650 129.0 75 131 6348 Fow in s • m 121 Gallons /stroke 2.8 Mud Data: Density (ppg) Viscosity Filtrate PV YP Chlorides FC PH Solids I Depth in out (sec/qt (cc /30 min) cP Ib /100ft (mg /I) (1/32" % 6140 9.1 9.1 48 6.9 9 26 1,400 1 9.3 4.0 BIT DATA: Type Size TFA Hours Depth in / out Footage WOB RPM Condition Bit # 1 DTX619M 8.50 0.78 4.5 5879 675 12 -15 60 1 Bit # -- _ - -_ - -- Lithology ( %): Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Tuff Chrt 80 - -_ 20 - - - - - -- Connection Gas and Mud Cu Wiper Trip gas I ft units ppg ft units ppg ft units ppg 24 hour Gas Breakdown Gas (units) Chromatograph (ppm) I Bit Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 5859 to 6421 107 75 6680 BG 6421 to 6494 155 21060 GP I to to to to I to to to to I to to to I to to to 1 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas - 24 hr Recap: Test BOPs H2s alarm went off secure well, RIH , Drilling 8 1/2 hole at report time. 1 1 G & I Magnets: lbs Rig Magnets: Ibs Total Metal cuttings: Logging Engineer: Steven Jenkins/ Wayne Hermanson * 10000 units = 100% Gas In Air 1 1 II Customer: B.P.X Alaska Report #: 2 Well: 2- 30B -ME -01 Date: 28/02/2008 Sparry =Willing Sarvic�s Area: Endicott 24 :00 Depth: 8609 Progress 24 hrs: 2060 Rig: Doyon -14 Rig Activity: Drilling Mudlogger's Morning Report Job No.: AK -AM- 0006247187 Report For: Company Man I Daily Cost: $2,791 Cumulative Cost: $21,360 ROP &Gas: Current 24 hr Avg 24 hr Max Max @ ft Pump & Flow Data: I R.O.P. ft/hr 195.0 215.0 401.0 7269 Flow in •.m 540 SPP •si 1770 112.0 156 6072 6748 Fow in s•m 129 Gallons /stroke 4.2 Mud Data: Density (ppg) Viscosity Filtrate PV YP Chlorides FC PH Solids Depth in out sec /qt) (cc /30 min) cP (Ib /100ft m. /I (1/32 ") ok U 6140 9.1 9.1 48 7.2 7 28 1,300 1 9.1 4.0 BIT DATA: Type Size TFA Hours Depth in / out Footage WOB RPM Condition Bit # 1 DTX619M 8.50 0.78 5879 2730 15 -40 80 -90 Bit # -- _ - -_ - -- Lithology ( %): Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Tuff Chrt 1 9 0 - - 10 - - - - -- Connection Gas and Mud Cu Wiper Trip gas ft units ppg ft units ppg ft units ppg I 24 hour Gas Breakdown Gas (units) Chromatograph (ppm) I Bit Depth Max Average C1 C2 1 C3 C4 Tot C5 Tot Type 6494 to 6720 179 81 10572 0 0 0 BG 6720 to 6762 6072 2564 324326 0 0 0 0 PG I 6762 to 7860 514 86 41762 1 0 0 0 BG 7860 to 7877 511 196 62576 4 2 0 0 PK 7877 to 8328 287 92 36965 1 0 0 0 BG 8328 to 8558 356 155 17784 9 1 0 0 BG I to to to I to to to to I to to to 111 I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas 24 hr Recap: Continue to drill 8 1/2" Hole Section. 1 1 Logging Engineer: Eugene Payne/ Wayne Hermanson * 10000 units = 100% Gas In Air 1 I Customer: B.P.X Alaska Report #: 3 Well: 2- 30B -ME -01 Date: 01/03/2008 Sperry Grilling services Area: Endicott 24 :00 Depth: 10670 Progress 24 hrs: 2061 Rig: Doyon -14 Rig Activity: Drilling Mudlogger's Morning Report Job No.: AK -AM- 0006247187 Report For: Company Man I Daily Cost: $2,791 Cumulative Cost: $24,151 ROP &Gas: Current 24 hr Avg 24 hr Max Max @ ft Pump & Flow Data: I R.O.P. ft/hr 191.0 147.0 9831.0 9831 Flow in • • m 540 SPP •si 2150 40.0 79 367 9192 Flow in s•m 128 Gallons /stroke 4.2 Mud Data: Density (ppg) Viscosity Filtrate PV YP Chlorides FC PH Solids Depth in out sec./qt) cc /30 min) cP Ib/100ft (m• /I (1/32 ") % 1 10675 9.2 9.2 43 6.4 10 21 950 1 8.4 5.0 BIT DATA: Type Size TFA Hours Depth in / out Footage WOB RPM Condition Bit # 1 DTX619M 8.50 0.78 5879 4791 15 -40 80 -90 Bit # -- - - - - - -- Lithology ( %): Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Tuff Chrt 1 90 10 1 Connection Gas and Mud Cu Wiper Trip gas 1 ft units ppg ft units ppg ft units ppg I 24 hour Gas Breakdown Gas (units) Chromatograph (ppm) I Bit Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 8558 to 10580 367 79 10269 2 0 0 0 BG to I to to to to I to to to to I to to to I to to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas 24 hr Recap: Continue to drill 8 1/2" Hole Section. 1 II I Logging Engineer: Eugene Payne/ Wayne Hermanson * 10000 units = 100% Gas In Air 1 1 I rta Customer: B.P.X Alaska Report #: 4 Well: 2- 30B -ME -01 Date: 02/03/2008 Sperry C:1riIIing services Area: Endicott 24 :00 Depth: 11534 I Progress 24 hrs: 11534 Rig: Doyon -14 Rig Activity: Drilling Mudlogger's Morning Report Job No.: AK -AM- 0006247187 Report For: Company Man I Daily Cost: $2,791 Cumulative Cost: $26,942 ROP &Gas: Current 24 hr Avg 24 hr Max Max © ft Pump & Flow Data: R.O.P. ft/hr 137.0 333.0 10767 Flow in • •m 540 SPP •si 2150 50 130 10826 Flow in s•m 128 Gallons /stroke 4.2 Mud Data: Density (ppg) Viscosity Filtrate PV YP Chlorides FC PH Solids Depth in out (sec/qt) cc /30 min) cP Ib /100ft (mg /I) 1/32" % I 10675 9.2 9.2 43 6.4 10 21 950 1 8.4 5.0 BIT DATA: Type Size TFA Hours Depth in / out Footage WOB RPM Condition Bit # 1 DTX619M 8.50 0.78 36.5 5859 5675 15 -40 80 -90 Bit # -- -_ - - -- Lithology ( %): Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Tuff Chrt 1 90 10 Connection Gas and Mud Cu Wiper Trip gas I ft units ppg ft units ppg ft units ppg 24 hour Gas Breakdown Gas (units) Chromatograph (ppm) I Bit Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 10580 to 11534 130 50 16904 55 21 22 3 BG to I to to to to I to to to I to to to to I to to to 111 I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas 24 hr Recap: Drill 8 1/2" hole from 10,670 to 11,534'. I i Logging Engineer: Eugene Payne/ Wayne Hermanson * 10000 units = 100% Gas In Air 1 1 I Customer: B.P.X Alaska Report #: 5 1-4"1-1-3 E3Li Pri MI Well: 2- 30B -ME -01 Date: 03/03/2008 Sparry Oriiiirig S®rvicas Area: Endicott 24 :00 Depth: 12147 Progress 24 hrs: 613 Rig: Doyon -14 Rig Activity: Drilling Mudlogger's Morning Report Job No.: AK -AM- 0006247187 Report For: Company Man I Daily Cost: $2,791 Cumulative Cost: $29,733 ROP &Gas: Current 24 hr Avg 24 hr Max Max @ ft Pump & Flow Data: ER R.O.P. ft/hr 29.0 107.0 267.0 11621 Flow in ..m 544 SPP .si 2000 15.0 39 94 11586 Flow in s• m 130 Gallons /stroke 4.2 Mud Data: Density (ppg) Viscosity Filtrate PV YP Chlorides FC PH Solids Depth in out (sec/qt (cc /30 min) cP lb /100f1 m. /1) (1/32 ") % I 12096 9.3 9.3 50 5.0 11 30 700 1 9.2 6.0 BIT DATA: Type Size TFA Hours Depth in / out Footage WOB RPM Condition Bit # 1 DTX619M 8.50 0.78 36.5 5859 6288 15 -40 80 -90 Bit # --- - - - - -- Lithology ( %): Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Tuff Chrt 1 60 - 20 20 - - -- Connection Gas and Mud Cu Wiper Trip gas I ft units ppg ft units ppg ft units ppg 24 hour Gas Breakdown Gas (units) Chromatograph (ppm) I 39 Bit Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 11534 to 12118 94 4527 57 14 3 0 BG to I to to to to I to . to to I to to to to to to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas 24 hr Recap: Drill 8 1/2" hole from 11, 534 to 12, 147'. i 1 1 Logging Engineer: Eugene Payne/ Wayne Hermanson * 10000 units = 100% Gas In Air 1 I Customer: B.P.X Alaska Report #: 6 �..__._ Well: 2- 30B -ME -01 Date: 04/03/2008 Sperry Oriiiing Services Area: Endicott 24 :00 Depth: 12697 I Progress 24 hrs: 550 Rig: Doyon -14 Rig Activity: Drilling Mudlogger's Morning Report Job No.: AK -AM- 0006247187 Report For: Company Man II Daily Cost: $2,791 Cumulative Cost: $32,524 ROP &Gas: Current 24 hr Avg 24 hr Max Max @ ft Pump & Flow Data: I R.O.P. ft/hr 10.0 35.0 258.0 12425 Flow in ..m 557 SPP .si 1530 30.0 38 157 12614 Flow in s.m 132 Gallons /stroke 4.2 Mud Data: Density (ppg) Viscosity Filtrate PV YP Chlorides FC PH Solids Depth in out (sec /qt cc/30 min) cP Ib /100ft (mg /I 1/32 ") % I 12658 10.4 10.4 46 3.5 12 17 1,400 1 9.5 8.5 BIT DATA: Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1 Bit # 1 DTX619M 8.50 0.78 36.5 5859 6838 15 -40 80 -90 Bit # - __ - - - - -- Lithology ( %): Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Tuff Chrt 1 40 -- 20 40 Connection Gas and Mud Cu Wiper Trip gas ft units ppg ft units ppg ft units ppg 24 hour Gas Breakdown Gas (units) Chromatograph (ppm) 1 I Bit Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 12118 to 12684 157 38 4527 57 14 3 0 BG 12614 to 157 67 WTG I to to to to I to to to to to to to I to to to z Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas , 24 hr Recap: Drill 8 1/2 " hole from 12, 147' to 12, 559'. Complete wiper trip to 11, 052', seen 157 units of Trip Gas when circulating back on bottom. Drill from 12, 559' to 12, 612'. Displace mud system to 10.5 LSND. Drill from 12, 612' to 12, 697'. I I. 1 Logging Engineer: Eugene Payne/ Wayne Hermanson * 10000 units = 100% Gas In Air 1 1 I Customer: B.P.X Alaska Report #: 7 1-4"14.1-1 M Li Frrc3rhi Well: 2- 30B -ME -01 Date: 05/03/2008 S r pary Or ar illir•g Svicas Area: Endicott 24 :00 Depth: 13174 i Progress 24 hrs: 477 Rig: Doyon -14 Rig Activity: Drilling Mudlogger's Morning Report Job No.: AK -AM- 0006247187 Report For: Company Man I Daily Cost: $2,791 Cumulative Cost: $35,315 ROP &Gas: Current 24 hr Avg 24 hr Max Max @ ft Pump & Flow Data: I R.O.P. ft/hr 16.0 128.0 196.0 13090 Flow in •.m 560 SPP .si 2670 IMIESIMIE 24 43 103 13030 Flow in s•m 134 Gallons /stroke 4.2 Mud Data: Density (ppg) Viscosity Filtrate PV YP Chlorides FC PH Solids I Depth in out (sec/qt) (cc/30 min cP Ib /100ft (m. /I (1/32 ") % 13156 10.3 10.3 53 3.2 15 34 1,250 1 8.8 12.0 BIT DATA: Type Size TFA Hours Depth in / out Footage WOB RPM Condition Bit # 1 DTX619M 8.50 0.78 5859 7315 15 -40 80 -90 Bit # -- _ - - - - -- Lithology ( %): Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Tuff Chrt 1 20 40 40 - - -_ -- Connection Gas and Mud Cu Wiper Trip gas I/ ft units ppg ft units ppg ft units ppg 24 hour Gas Breakdown Gas (units) Chromatograph (ppm) I Bit Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 12684 to 13170 103 43 4082 109 43 29 15 BG to I to to to to I to to to I to to to to I to to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas ii 24 hr Recap: Drill 8 1/2" hole from 12, 697' to 13, 174'. 1 Logging Engineer: Eugene Payne/ Wayne Hermanson * 10000 units = 100% Gas In Air i 1 1 I Customer: B.P.X Alaska Report #: 8 je Well: 2- 30B -ME -01 Date: 06/03/2008 Sperry Drilling Services Area: Endicott 24 :00 Depth: 13690' I Progress 24 hrs: 516 Rig: Doyon -14 Rig Activity: Drilling Mudlogger's Morning Report Job No.: AK -AM- 0006247187 Report For: Company Man I Daily Cost: $2,791 Cumulative Cost: $38,106 ROP &Gas: Current 24 hr Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. ft/hr 0.0 100.0 290.0 13560 Flow in • •m 560 SPP es' 2670 iii crnummim 0 448 1171 13680 Flow in s•m 134 Gallons /stroke 4.2 Mud Data: Density (ppg) Viscosity Filtrate PV YP Chlorides FC PH Solids I Depth in out sec /qt) cc /30 min) cP (Ib/100ft mg /I) 1/32" % 13690 10.5 10.5 49 3.3 16 31 1,200 0.33 8.9 14.0 BIT DATA: Type Size TFA Hours Depth in / out Footage WOB RPM Condition Bit # 1 DTX619M 8.50 0.78 5859 7831 15 -40 80 - Bit # -- _ - - - - -- Lithology ( %): Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Tuff Chrt 1 - - -_ -- 100 - - - -- Connection Gas and Mud Cu Wiper Trip gas I ft units ppg ft units ppg ft units ppg 24 hour Gas Breakdown Gas (units) Chromatograph (ppm) I Bit Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 13170 to 13230 66 40 4124 124 52 34 19 BG 13230 to 13690 1171 502 38411 2065 988 539 225 BG I to to to to I to to to to I to to to I to to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas 24 hr Recap: Drill 8 1/2" hole from 13, 174' to 13, 690'. r 1 Logging Engineer: Eugene Payne/ Wayne Hermanson * 10000 units = 100% Gas In Air 1 1 I Customer: B.P.X Alaska Report # 9 1-1- Lim Well: 2- 30B -ME -01 Date: 07/03/2008 i3parry Oriiiing sa. -vic ®s Area: Endicott 24 :00 Depth: 13827' Progress 24 hrs: 137 Rig: D oyon -14 Rig Activity: Drilling Mudlogger's Morning Report Job No.: AK -AM- 0006247187 Report For: Company Man 1 Daily Cost: $3,311 Cumulative Cost: $41,417 ROP &Gas: Current 24 hr Avg 24 hr Max Max © ft Pump & Flow Data: I R.O.P. ft/hr 122.0 55.0 171.0 13802 Flow in ..m 500 SPP isi 2300 WEEIMEr- 351 1392 6538 13821 Flow in s.m 119 Gallons /stroke 4.2 Mud Data: Density (ppg) Viscosity Filtrate PV YP Chlorides FC PH Solids Depth in out (sec /qt cc/30 min cP Ib /100ft m. /I) (1/32" % 13708 10.6 10.6 51 3.1 16 30 1,150 0.33 8.8 14.0 BIT DATA: Type Size TFA Hours Depth in / out Footage WOB RPM Condition I Bit # 2 MSX616M 8.50 0.72 13690 - - -- Bit # 1 DTX619M 8.50 0.78 71.24 5859 13690 7831 15 -40 80 -90 Lithology ( %): Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Tuff Chrt _ - - - -� 1 100 - -� -- Connection Gas and Mud Cu Wiper Trip gas I ft units ppg ft units ppg ft units ppg 24 hour Gas Breakdown Gas (units) Chromatograph (ppm) I Bit Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 13690 to 2686 201758 11112 5657 2984 1154 TG 13690 to 13793 411 294 26740 1708 880 576 291 BG I 13793 to 13827 6538 292034 34452 12903 4799 1653 PK to to to I to to to I to to to to I to to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas 24 hr Recap: Continue POOH. Pick up new BHA and test tools. RIH to 13545'. Mad pass 13600' to 13690'. Drill 1 to 13, 827'. 1 I '. Logging Engineer: Eugene Payne/ Wayne Hermanson * 10000 units = 100% Gas In Air 1 1 I Customer: B.P.X Alaska Report #: 10 I-LOA-LAE Li Fri Well: 2- 30B -ME -01 Date: 08/03/2008 Sperry Drilling Services Area: Endicott 24 :00 Depth: 14207' III Progress 24 hrs: 380 Rig: Doyon -14 Rig Activity: POOH Mudlogger's Morning Report Job No.: AK -AM- 0006247187 Report For: Company Man I Daily Cost: $3,311 Cumulative Cost: $44,728 ROP &Gas: Current 24 hr Avg 24 hr Max Max @ ft Pump & Flow Data: in R.O.P. ft/hr 0.0 42.0 133.0 13902 Flow in ..m 500 SPP •si 2200 36 534 2898 13854 Flow in s•m 119 Gallons /stroke 4.2 Mud Data: Density (ppg) Viscosity Filtrate PV YP Chlorides FC PH Solids Depth in out sec/qt) cc/30 min) cP (Ib /100ft m. /I) (1/32 ") % 1 13708 10.6 10.6 51 3.1 16 30 1,150 0.33 8.8 14.0 BIT DATA: Type Size TFA Hours Depth in / out Footage WOB RPM Condition I Bit # 2 MSX616M 8.50 0.72 13690 14207 517 -- Bit # 1 DTX619M 8.50 0.78 71.24 5859 13690 7831 15 -40 80 -90 Lithology ( %): Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Tuff Chrt 1 70 -�- 30 Connection Gas and Mud Cu Wiper Trip gas I ft units ppg ft units ppg ft units ppg 24 hour Gas Breakdown Gas (units) Chromatograph (ppm) I Bit Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 13854 to 2898 21176 16498 6635 2734 1030 PK 13869 to 14046 899 399 31067 2798 1463 840 418 BG 14054 to 2507 199367 13504 5204 2283 924 PK I 14080 to 14170 1050 446 35757 3021 1394 762 390 BG 14170 to 14207 254 154 11235 1340 861 596 337 BG to I to to to I to to to to I to to to a Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; II POG - pumps off gas r 24 hr Recap: Drill 8 1/2" hole from 14, 827' to TD of 14, 207'. 1 1 Logging Engineer: Eugene Payne/ Wayne Hermanson * 10000 units = 100% Gas In Air 1 1 I Customer: B.P.X Alaska Report #: 11 ` Well: 2- 30B -ME -01 Date: 09/03/2008 Sperry Oriu:ng Mar-vioas Area: Endicott 24 :00 Depth: 14207' II Progress 24 hrs: 0 Rig: D oyon -14 Rig Activity: POOH Mudlogger's Morning Report Job No.: AK -AM- 0006247187 Report For: Company Man Daily Cost: $2,900 Cumulative Cost: $47,628 ROP &Gas: Current 24 hr Avg 24 hr Max Max @ ft Pump & Flow Data: R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • •m 500 SPP •si 2200 I � 0 41 194 14207 Flow in s•m 119 Gallons /stroke 4.2 Mud Data: Density (ppg) Viscosity Filtrate PV YP Chlorides FC PH Solids Depth in out (sec /qt (cc/30 min) cP Ib /100ft (mg /I) 1/32 ") % I 13708 10.6 10.6 51 3.1 16 30 1,150 0.33 8.8 14.0 BIT DATA: Type Size TFA Hours Depth in / out Footage WOB RPM Condition I Bit # 2 MSX616M 8.50 0.72 9.15 13690 14207 517 15 -25 150 -254 Bit # 1 DTX619M 8.50 0.78 71.24 5859 13690 7831 15 -40 80 -90 Lithology ( %): Sd Sst Silt Siltst Cly Clyst Sh Lst Coal Tuff Chrt 111 70 ��- 30 Connection Gas and Mud Cu Wiper Trip gas I ft units ppg ft units ppg ft units ppg 24 hour Gas Breakdown Gas (units) Chromatograph (ppm) Bit Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 14114 to 194 STG to I to to t to 1 to to to to I to to to I to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; POG - pumps off gas I 24 hr Recap: Finish up downhole logging program. Pull out of hole for short trip from 14, 207' to 11, 661'. Run in hole to 14, 114'. Establish circulation with 194 units of short trip gas seen on bottoms up. Spot G -seal pill at 13, 830' and pull out of hole to surface. I Logging Engineer: Eugene Payne/ Wayne Hermanson * 10000 units = 100% Gas In Air 1 1 i MN r — A 1— NM 1 S NB all NM S i S r NE an HALLIBURTON WELL NAME: END 2- 30B/ME -01 LOCATION: Prudhoe Bay bp OPERATOR: BP Exploration Alaska, Inc. AREA: Endicott CONTRACTOR: Doyon 14 STATE: Alaska Sperry Drilling Services 0 BIT RECORD BHA Bit Bit Bit Depth Depth Footage Bit TFA AVG WOB RPM SPP FLOW GPM Bit Grade Remarks # # Type Size IN OUT Hours ROP Amax! , (max) (max) (max) 1 1 DTX619M 8.50 5859 13690 7831 71.24 0.780 109.9 15-25 150 -254 2850 550 POOH to pick up new BHA 2 2 DTX619M 8.50 13690 14207 517 9.15 0.720 56.5 15 - 25 150 2540 520 Total Depth OM MN MB NM NM W M I i UM I- I NM NM I V- N HALLIBURTON Casing Record Sperry Drilling Services Comparr BP Alaska Exploration Inc. Area Prudhoe Bay Well: END 02 -30B / ME 01 Job No: AK -AM- 0006247187 9 -5/8" at 5859' MD Rig: Doyon 14 Spud Date 27 Feb 2009 Water -based Mud Record Mud Co: MI Swaco TD Date: 7 Mar 2009 Date Depth Wt Vis PV YP Gels Filt R6001R3001R2001R7001R61R3 Cake Solids Water /Oil Sd Pm pH MBT PfIMf Chlor Hard Remarks ft - MD ppg sec lb /100 Ib /100ft m/30m Rheometer 32nds % % % mg /L(K) Ca ++ 26 -Feb 6164 9.10 48 9 26 11/15/16 6.9 44/35/30/24/12/11 1 4.0 96.0 0.27 9.3 5.0 0.53/0.14 1.4 50 Test BOP's & drill 8 -1/2" 27 -Feb 8601 9.10 43 8 24 11/16/20 7.2 40/32/27/22/11/10 1 4.0 94.0 tr 0.05 8.3 12.5 0.05/0.35 1.3 20 Drill 8 -1/2" hole 28 -Feb 10675 9.20 43 10 21 10/14/19 6.4 41/31/26/21/10/9 1 5.0 94.0 tr 0.00 8.4 17.5 0/0.43 1.0 20 Drill 8 -1/2" hole 01 -Mar 11480 9.30 47 11 22 10/14/18 5.3 44/33/28/22/11/9 1 5.0 93.0 tr 0.10 9.2 17.5 0.05/0.65 0.9 20 Drill 8 -1/2" hole, WOW 02 -Mar 12096 9.30 50 11 30 16/19/22 5.0 52/41/36/30/14/11 1 6.0 91.0 tr 0.15 9.2 20.0 0.10/0.50 0.7 20 Drill 8 -1/2" hole 03 -Mar 12658 10.40 45 12 17 6/8/9 3.5 41/29/25/18/6/5 1 8.5 90.0 tr 0.20 9.5 7.5 0.15/1.0 1.4 60 Drill 8 -1/2" hole 04 -Mar 13156 10.30 52 15 34 15/17/20 3.2 64/49/41/32/15/13 1 12.0 3/85 tr 0.05 8.8 7.5 0.00/1.40 12.5 44 Drill 8 -1/2" hole 05 -Mar 13690 10.50 48 17 28 13/15/18 3.2 62/45/39/30/14/11 1 14.0 5/81 tr 0.05 8.9 10.0 0.02/1.40 1.2 40 Trip 06 -Mar 13708 10.60 51 16 30 13/14/17 3.1 62/46/40/31/14/12 1 14.0 5/81 tr 0.03 8.8 12.0 0.00/1.40 1.2 40 Drill 8 -1/2" hole 07 -Mar 14207 10.50 51 12 32 14/16/19 3.4 64/48/41/32/15/13 1 13.0 5/82 tr 0.05 9.0 12.5 0.02/1.40 1.1 40 Drill to TD @ 14207' 08 -Mar 14207 10.50 49 13 27 11/13/15 3.4 53/40/34/28/12/10 1 13.0 5/82 tr 0.05 8.9 12.5 0.03/1.40 1.0 40 POOH I I 1111; sperry-sun Well Name: BP END 2-30-BIN Depth (MD) 13800 to 13862 ft jr Location: North Slope, Alaska (TVD) 9829 to 9888 ft 1111 I Show Report DRILLING SERVICES Date/Time: Operator: BP Exploration, Alaska Report Prepared By: Wayne Hermanson/Eugene Payne Show Report No. 1 1:11 07-Mar-09 Report Delivered To Donna Messer/Curt Goddard I 1111 Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. 1111 Sandstone : It gy brn, wh, clr, slty-vf gr, ang-sb ang, w srtd, sil cmt, pred v fri, pred qtz, abnt pyr, tr glauc, thin calc vns, oil stn, brit yel flour, slo strmg 1111 pale blu wh ct. Pixler plot indicates Ga/Oil zone. I . . . . ............. . . .. . ......,........................... ....... . . . . . . . . . . ........................-- .,. .. . . .. . . . . . „ . . . . . . . ....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ............................ Hydrocarbon Ratios - Depth 13821 ft Gas x Units 6538 Mud Chlorides (1000's) Cl Cl Cl Cl MI I nd Flowline BackgrouShow ppm C2 C3 C4 C5 Pm PPm PPm N. Hydrocarbon Ratios 1000.0 11! Cl 292034 - 19911 = 272123 C1/C2 = 8.3 I 11 i g C2 34452 - 1629 = 32823 C1/C3 = 22.5 !!!!1 C3 12903 - 812 = 12091 C1/C4 = 63.1 I !I:1i C4 4822 - 507 = 4315 C1/C5 = 195 NPH IR C5 1653 - 258 = 1395 I .. Production Analysis nGas Oil nWater nNon-Producible Hydrocarbons 100.0 -- rxi 11 - - .. ... - - 1111:21 % I Depth 13853 ft Gas NUnits 2887 Mud Chlorides (1000 Gas s) , 3:. Flowline Background Show PPm PPm PPm ___________ Hydrocarbon Ratios 100 III Cl 211174 - 19911 = 191263 C1/C2 = 13.0 -. I pill C2 16352 - 1629 = 14723 C1/C3 = 33.9 1111 C3 6458 - 812 = 5646 C1/C4 = 91.4 08 ..: 1111. C4 2600 - 507 = 2093 C1/C5 = 258 I 11111 C5 998 - 258 = 740 illll Production 1.0 I Analysis nGas NOil nWater nNon-Producible Hydrocarbons NPH HILLI .... % Hydrocarbon Ratios I IIII1 Depth ft Gas x Units Mud Chlorides s (1000's) Cl Cl Cl Cl C2 C3 III C4 C5 Illf PPm ppm ppm Hydrocarbon Ratios I Cl = C1/C2= PI C2 - - = C1/C3 = - 1000.0 C3 - = C1/C4 = - NPH Ir! C4 - = C1/C5 = I 1 I 1 r C5 Production = 100.0 - ...,..- - . _ ... - ''' ...- 11111 Analysis nGas foil nWater nNon-Producible Hydrocarbons ...... - - -- .: •., i Depth ft B Gas HUnits Mud Chlorides (1000's) : Gas Flowline Background Show _ ----- - - - - -. - - - - - - PPm ppm ppm 11 I C 1 ! ! ! ! ! C2 = Hydrocarbon Ratios C1/C2 = C1/C3 = 10.0 Oil 1.11 !!!!: C3 = C1/C4 = I ii C4 Ill C5 = = C1/C5 = ______ NPH 1.0 HI Production 11111 Analysis nGas foil nWater nNon-Producible Hydrocarbons I I I I . . . . , , . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. .............................................. ........ .................................... . . ..........„ . . . ... . . . . . . . . .,„ . „ ..„.....„ . . „ . . . . . . ....... . . . . . . . . . .... . . . . . ..... . . . . . . . . . . . . . .. . ..... ..................... . . . . . ...........-„,................................ - ............................. - :::::::: sperry-sun Well Name: BP END 2-30-B/N Depth (MD) 13960 to 14005 ft Location: North Slope, Alaska (ND) 9982 to 10025 ft MO I '... DRILLING SERVICES Show Report Operator: BP Exploration, Alaska Report Prepared By: Wayne Hermanson/Eugene Payne Show Report No. 2 1 Date/Time: 07-Mar-09 Report Delivered To: Donna Messer/Curt Goddard 11111 ..., I 1111 Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. yly: Conglomerate : wh, It gy, off wh, blk, pred cht, qtz, ang chips from peb & gravl. MI Pixler plot indicates Gas zone. Samples indicate poor possibibility for oil. I NI 1 LA% Hydrocarbon Ratios Depth 13977 ft Gas 12dUnits 899 Mud Chlorides (1000's): Cl Cl Cl Cl I '1 Flowline Background Show .,.: PPm ppm ppm C3 C4 11111 I DID Hydrocarbon Ratios 1000 li Cl 76079 - 5254 = 70825 c1ic2 = 15 A I C2 5539 - 816 = 4723 c1/c3 = 45 1 1111 C3 2305 - 740 = 1565 C1/C4 = 135 1111 C4 1086 - 560 = 526 C1/C5 = 451 NPH a C5 480 - 323 = 157 - • I I Production - — 11 Analysis nGas r nNon-Producible Hydrocarbons 100 - -- — — — - ---- 1 111 1 1'' 1 11. 11 1.1 .- 2 LI % 1111 Depth 13987 ft Gas 1 Units 802 Mud Chlorides (1000's) G : • IN Flowline Background Show PP m PPm PPm ----------- g Hydrocarbon Ratios 10 - lill Cl 71810 - 5123 = 66687 C1/C2 = 15 , .. I :RI C2 5117 - 794 = 4323 C1/C3 = 47 - C3 2111 - 699 = 1412 C1/C4 = 144 OR 1111 C4 983 - 519 = 464 C1/C5 = 473 • I 01. C5 438 - 297 = 141 :III Production HI: Analysis nGas fl Oil nWater fl Non-Producible Hydrocarbons NP-1 1 r 3 H% Cl Hydrocarbon Ratios I I..: Depth 14005 ft Gas Units 614 Mud Chlorides (1000 Cl Cl Cl 0 . $) : Flowline Background Show C2 C3 C4 C5 Doi PPm ppm ppm ril Hydrocarbon Ratios 1000.0 I ,41 Cl 54089 - 5123 = 48966 C1/C2 = 15 C2 4029 - 794 = 3235 C1/C3 = 47 ' t C3 1739 - 699 = 1040 clic = 146 .:'. NPH Igil C4 855 - 519 = 336 c1iC5 = 505 I d : C5 394 Production - 297 = 97 100.0 _ - - - -.- — -' Analysis nGas nOil nWater n Non-Producible Hydrocarbons — -- "" _ — I Depth ft Gas N Units Mud Chlorides (1000's) . Gas Flowline Background Show --------- — — — —, 11 PPm PPm PPm I Hydrocarbon Ratios 10.0 Cl = C1/C2 ' C2 - = C1/C3 = Oil li C3 - = C1/C4 = I C4 - _ = = C1/C5 = C5 — NPH — — — — Production 1.0 - Analysis Gas I Oil I Water II Non-Producible Hydrocarbons I '''. 4 44277.mi! , . , .11. 1 goliii44gmismilimanomininemonom,,„0:001,1,11,1,11,0„,01131,113101011111,0021111,1,10usummonommummonsomumismoinim I I I; IMP OM ill IWIIIINNiry ..M1011111111115! 0111111111i le MI iibiniiilri EVAN arnagifialiAgilii&R , tii■: , n;:'':-_F„_gt , 'iiI_iar_ i_'Iiiifi;_t 1 IIIPMEIMIT:: li■ 1 sperry-sun Well Name: BP END 2-30-B/N Depth (MD) 14035 to 14080 ft h Location: North Slope, Alaska (TVD) 10054 to 10097 ft 14. • g DRILLING SERVICES T :,. Operator: BP Exploration, Alaska Show Report Report Prepared By: Wayne Hermanson/Eugene Payne Date/Time: Report No. 3 q. 07-Mar-09 — !II iii Report Delivered To: Donna Messer/Curt Goddard ..., I r Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. ill Sandstone: clr, trsp, wh, vf-m gr, sb ang-sb rd, w srtd, v fri, pred qtz„ dl yel nat flour, brit ip, fst mlky wh blmg cut. Pixler plot indicates possible oil zone I Samples confirm good oil zone. 11 111 E1 1% Hydrocarbon Ratios Depth 14041 ft Gas 11 Units 655 Mud Chlorides (1000's) , Cl Cl Cl Cl h' I 0 Flowline Background Show ppm ppm ppm C2 C3 C4 C5 il11 Hydrocarbon Ratios 1000 Cl 22921 - 7070 = 15851 C1/C2 = 9 I II C2 2633 - 846 = 1787 C1/C3 = 11 1 C3 2175 - 722 = 1453 C1/C4 = 23 1 1 1111 C4 1235 - 558 = 677 C1/C5 = 59 NPHisiroo.o..............0. 9 C5 605 - 335 = 270 ....- I ti Production 14 Analysis g Gas El Oil I Water I Non-Producible Hydrocarbons 4 100 a ......-- _ ------- . ... ■ — — - 4 10 il I 1 Depth 14048 ft Gas 15 Units 2361 w Mud Chlorides (1000's) , I . ;Ii0 Flowline Background Sho PPm PPm PPm Gs .! ----- ' Hydrocarbon Ratios 10 -- 0 Cl 189833 - 7070 = 182763 C1/C2 = 15 I Id C2 12758 - 846 = 11912 C1/C3 = 43 9 C3 4958 - 722 = 4236 C1/C4 = 113 Oil , ---'4 326 C4 2176 - 558 = 1618 C1/C5 = ji t4 II ,„,,,, C5 ., 4 Production 895 - 335 = 560 111 Analysis nGas 131( Oil nWater n Non-Producible Hydrocarbons NP - t 1 . ., ' 4 El % Hydrocarbon Ratios i I ,11 11 Depth 14064 ft Gas HUnits 1283 Mud Chlorides (1000's) , ,.. Cl Cl Flowline Background Show C2 C3 Cl Cl 't C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000.0 I C1 111152 - 7070 = 104082 C1/C2 = 15 '.. C2 7577 - 846 = 6731 C1/C3 = 45 C3 3046 - 722 = 2324 C1/C4= 119 NPH A C4 1430 - 558 = 872 C1/C5 = 360 - 9 I Production . :! C5 624 - 335 = 289 — -- — ' 0 100.0 — „. — 01 Analysis I Gas lil Oil I Water I Non-Producible Hydrocarbons — — :14 11 Y iti Depth 1'11 ft Gas El Units Flowline Background Show PPm PPm PPm Mud Chlorides (1000's) , Gas ------ 0, 0 I Hydrocarbon Ratios 10.0 C1 - = :0 = C1/C2 = C2 - C1/C3 = — Oil = _.... , C3 - Cl/C4 = -,, — I _I C4 , - - = Cl /C5 = C5 = — NPH — A i Production 1.0 . :11 Analysis U Gas I Oil I Water • Non-Producible Hydrocarbons I 11411.144114441141111101114,11101 1 1 1 144114111410,411444M 4 4 1 41 1 144 1114,1444 4 41111116114441111111111444111111111111111411111411111111111111114444444 MOMM 4 0 0 44 1 , 4141 444410 1 14 4 4 1 4!!!!!!!!!!!!!!!!!!!!!!!!!!!! I END 2- 30B /ME -01 I 5000 Days vs Depth I This well is a sidetrack from original hole 2- 30A/E1 -02 accomplished by I milling a window between 5818.8' to 5859.0'. The well was designed to intersect the Ivishak /Sag production in a new fault block 6000 Drill 8 -1/2" Hole Section i 7000 I 8000 III 9000 I 0. d I 10000 --0— a) L 3 I N co a) 11000 -- 1 — ' 12000 M11111111111111=111111111 .._ Y- 13000 M11111111111111111111111111111111 _ 14000 1111111111111111111111111111111111111•1111111111111 Total Depth 1420714D710218.73' ND , 111111111111111111111111111111111, , 1 15000 0 ' — 1- 0 5 10 15 Rig Days I I I Summarized Inventory I Biostrat Box # Depths 1 13,700- 13,780 2 13,790- 13,830 Pit Mud I Box # 1 Depths 13,126 1 13,690 I 1 14,207 GeoChemical Box # Depths I 1 13,730- 13,840 2 13,850- 13,960 3 13,970 -14070 1 4 14,070- 14,180 Dry Cuttings Box # Depths 1 5,900- 12,200 2 12,300- 14,000 I 3 14,000- 14,207 !so Tube Box# Depths I 1 2 13,730- 13,960 13,970- 14,080 I I I I I I I I I I BioStrat Sample - Inventory I Box # Smpl # Sample depth and 1 1 13700 1 2 13710 1 3 13720 4 13730 I i 1 5 13740 1 6 13750 1 7 13760 I 1 8 13770 1 9 13780 2 10 13790 I 2 11 13800 2 12 13810 2 13 13820 I 2 14 13830 I Ship to: Document Storage Inc. I c/o Joel Rupp 2410 East 88th Avenue Anchorage, AK 99507 I Phone: 907- 522 -2521 Fax: 907 - 522 -2686 I I I I I I I I I ( Pit Mud Sample - Inventory Box # Smpl # Sample depth and 1 1 1 1 13,126 2 13,690 1 3 14,207 Shi p to: Document Storage Inc. do Joel Rupp 2410 East 88th Avenue Anchorage, AK 99507 Phone: 907 - 522 -2521 Fax: 907 - 522 -2686 1 1 I I 1 I i I I IGeochemical Samples - Inventory I Box # Smpl # Sample depth Box # Smpl # Sample depth and and II 1 1 13730 3 26 13970 2 13740 3 27 13980 1 3 13750 3 28 13990 l 1 4 13760 3 29 14000 1 5 13770 3 30 14010 1 6 13780 3 31 14020 1 7 13790 3 32 14030 1 8 13800 3 33 14040 1 9 13810 3 34 14050 1 10 13820 3 35 14060 1 11 13830 3 36 14070 1 12 13840 4 37 14080 2 13 13850 4 38 14090 I 2 14 13860 4 39 14100 2 15 13870 4 40 14110 2 16 13880 4 41 14120 2 17 13890 4 42 14130 I 2 18 13900 4 43 14140 2 19 13910 4 44 14150 2 20 13920 4 45 14160 I 2 21 13930 4 46 14170 2 22 13940 4 47 14180 2 23 13950 I 2 24 13960 3 25 13970 I Ship to: Baseline Resolution /Weatherford Laboratories do Stephen R. Palmer 1 143 Vision Park Blvd. Shenandoah, TX 77384 281 - 681 -2200 (main) I 281- 791 -3104 (direct) stephen .palmer(cDweatherfordlabs.com I I I I I I I Dry Cuttings - Inventory 1 Box # Smpl # Sample depth Box # Smpl # Sample depth MD MD Ii 1 1 5900 1 43 10100 2 6000 1 44 10200 1 3 6100 1 45 10300 I II 1 4 6200 1 46 10400 1 5 6300 1 47 10500 1 6 6400 1 48 10600 1 7 6500 1 49 10700 Ii 8 6600 1 50 10800 1 9 6700 1 51 10900 1 10 6800 1 52 11000 1 11 6900 1 53 11100 1 12 7000 1 54 11200 1 13 7100 1 55 11300 1 14 7200 1 56 11400 1 15 7300 1 57 11500 1 16 7400 1 58 11600 1 17 7500 1 59 11700 1 18 7600 1 60 11800 1 19 7700 1 61 11900 1 20 7800 1 62 12000 1 21 7900 1 63 12100 1 22 8000 1 64 12200 1 23 8100 2 65 12300 Ii 24 8200 2 66 12400 1 25 8300 2 67 12500 1 26 8400 2 68 12600 1 1 27 8500 2 69 12700 1 28 8600 2 70 12800 1 29 8700 2 71 12900 1 30 8800 2 72 13000 1 31 8900 2 73 13100 1 32 9000 2 74 13150 1 33 9100 2 75 13200 1 34 9200 2 76 13250 1 35 9300 2 77 13300 1 36 9400 2 78 13350 1 1 37 9500 2 79 13400 1 38 9600 2 80 13450 1 39 9700 2 81 13500 Ii 40 9800 2 82 83 13550 1 41 9900 2 13600 1 42 10000 2 84 13650 1 2 85 13690 1 I I I Box # Smpl # Sample depth Box # Smpl # Sample depth I MD MD 2 86 13700 2 113 13970 2 87 13710 2 114 13980 I 2 88 13720 2 115 13990 2 89 13730 2 116 14000 2 90 13740 3 117 14010 2 91 13750 3 118 14020 I 2 92 13760 3 119 14030 2 93 13770 3 120 14040 2 94 13780 3 121 14050 I 2 2 95 13790 3 122 14060 96 13800 3 123 14070 2 97 13810 3 124 14080 I 2 98 13820 3 125 14090 2 99 13830 3 126 14100 2 100 13840 3 127 14110 2 101 13850 3 128 14120 2 102 13860 3 129 14130 2 103 13870 3 130 14140 2 104 13880 3 131 14150 I 2 105 13890 3 132 14160 2 106 13900 3 133 14170 2 107 13910 3 134 14180 I 2 108 13920 3 135 14190 2 109 13930 3 136 14200 2 110 13940 3 137 14207 I 2 111 13950 2 112 13960 1 Ship to: Document Storage Inc. 1 do Joel Rupp 2410 East 88th Avenue Anchorage, AK 99507 I Phone: 907-522-2521 Fax: 907 - 522 -2686 1 I I I I I I I lsotube Gas Samples - Inventory I Box # Smpl # Sample depth Gas Box # Smpl # Sample depth Gas and units and units 1 1 13730 166 2 25 13970 685 1 2 13740 339 2 26 13980 795 1 3 13750 355 2 27 13990 475 1 4 13760 354 2 28 14000 483 1 5 13770 310 2 29 14010 200 1 6 13780 267 2 30 14020 241 1 7 13790 318 2 31 14030 241 1 8 13800 2522 2 32 14040 320 1 9 13810 4964 2 33 14050 2650 1 10 13820 6505 2 34 14060 48 Ii 1 11 13830 263 2 35 14070 548 12 13840 1000 2 36 14080 48 1 13 13850 2850 1 14 13860 2020 1 15 13870 301 1 16 13880 380 1 17 13890 326 Ii 18 13900 309 1 19 13910 361 1 20 13920 650 Ii 21 13930 620 1 22 13940 855 1 23 13950 117 I 1 24 13960 544 Ship to: I Isotech Laboratories, Inc. do Sher Dixon I 1308 Parkland Court Champaign, IL 61821 Phone: 217- 398 -3490 I E -mail: dixon @isotechlabs.com I I I I I I I t ) INSITE, Sperry Inc. Customer Chromatograph Report 1 I 800 - I cc E m a I "Po E 2 L 400_ U o 0) 0 i 200 - I _ , d k s--1 \•-------) 1\•• _JV\___ 0 5 10 15 20 25 30 35 40 45 1 Time Since Inject (sec) I Date: Feb 28, 2009 Well: 2 -30B ME -01 Run: 100 I Mode: Calibration Logger: I Component Concentration (ppm) Cal. Factor Ret. Time (s) L.lim (s) R.Lim (s) Cl 10000 0.000670451 9.92 9.40 10.86 C2 4980 0.000336040 11.40 10.90 13.18 C3 5000 0.000218267 14.54 1372 18.40 I C4Iso 2500 0.000171173 20.12 18.78 21.12 C41)lam 2500 0.000167778 22.08 21.16 23.60 C54so 1000 0.000126688 35.92 33.48 37.90 CSNorm 1000 0.000127171 39.86 37.92 42.68 I I I I Sample Frequency. 50 Hz Oven Temperalue: 61 C Hyd'ogen Row 38 CC/min Air Flow. 200 CC/min I I I INSITE, Sperry Inc. I Customer Chromatograph Report I i 1 co i73 600 - E \\"\1/4.. ii, 2 a, o m 2 L 400 U C7 Z0D- 1 .. ) t _ ) Al\---, 0- r r r r r r r 0 5 10 15 20 25 30 35 40 45 11 Time Since Inject (sec) I Date: Mar 01, 2009 Well: 2-30B ME -01 Run: 100 I Mode: Calibration Logger: I Component Concentration (ppm) Cal. Factor Ret. Time (s) L.lim (s) R.Lim (s) Cl 10000 0.000675133 9.90 9.38 10.84 C2 4980 0.000337882 11.38 10.86 13.28 C3 5000 0.000219902 14.52 13.66 18.04 I C4Iso 2500 0.000172265 20.12 18.72 21.12 C4Nam 2500 0.000166401 22.10 21.16 23.62 C5Iso 1000 0.000127589 35.98 33.56 37.96 CSNam 1000 0.000128728 39.96 38.00 42.78 I I I I Sample Frequerxy. 50 Hz Overt Temperature: 61 C Hydngen Fb . 38 CC/mil Air Fbe 200 CC/min I INSITE, Sperry Inc. 4, j Customer Chromatograph Report I 1 800- o, 600- in I E 12 o, 0 m E ' 400 U 2 U 200- j 1 0 ■ 0 5 10 15 20 25 30 35 40 45 Time Since Inject (sec) 1 I Date: Mar 05, 2009 Well: 2-30B ME -01 Run: 100 Mode: Calibration 1 Logger: Component, Concentration (ppm) Cal. Factor Ret Time (s) 1 Llim (s) R.Ltm (s) I C1 10000 0.000684631 9.90 9.40 10.84 C2 4980 0.000343662 11.38 10.88 13.26 C3 5000 0.000223747 14.52 13.68 18.24 C4Iso 2500 T 0.000175757 20.08 18.76 L 21.08 C4Norm 2500 I 0.000172713 I 22.04 21.10 23.56 CSlso I 1000 I 0.000130679 35.76 I 33.28 , 37.74 C5Norm 1 1000 0.000132189 1 39.70 37.76 42.44 I I I I Sample Frequency: 50 Hz Oven Temperature: 61 C Hydrogen Flow 38 CC /min Air Flow 200 CC /min I I I , INSITE, Sperry Inc. t Customer Chromatograph Report 1 I I I I 800- 1 I To 600 I tm in co E i 2 E 400 U r 7 1 200- 1 0- 0 5 10 15 20 25 30 35 40 45 Time Since Inject (sec) I I Date: Mar 04, 2009 Well: 2-30B ME -01 Run: 100 Mode: Calibration I Logger: Component '' Concentration m Cal. Factor Ret Time s L.lim s RLim (s) (pp m) (s) ( ) C2 I C3 I 1 1 10000 0_ .000680831 9.90 9.40 10.84 5000 4980 i r 0.000339635 11.38 10.88 13.22 0.000221132 , 14.54 13.68 18.24 041so - 2500 - 0.000173013 20.12 18.74 21.14 -_ C4Norm 2500 1 0.000169273 I 22.10 21 16 I 23.64 I 1 CSlso 1000 0.000128316 35.98 33.52 37.96 C5Norm 1000 0.000128686 39.92 37.98 42.86 I I I i Sample Frequency: 50 Hz Oven Temperature: 61 C Hydrogen Flow. 38 CC /min Air Flow 200 CC /min I i I I INSITE, Sperry Inc. ) Customer Chromatograph Report I I 800 - II I To I in 600 - o i; E 1 ° 400- t U gi C7 1 200- \/ 0 0 5 10 15 20 25 30 35 40 45 Time Since Inject (sec) I I Date: Mar 03, 2009 Well: 2-30B ME-01 Run: 100 Mode: Calibration I Logger: Component' Concentration (ppm) ' Cal. Factor Ret Time (s) I L.IIm (s) R.Lim (s) I C1 10000 0.000672355 9.94 9.44 10 90 -- -- C2 4980 0.000336175 11.42 10.92 13.28 C3 5000 0.000219523 14.58 13.72 1794 C4Iso _I 2500 0.000172289 20.14 I 16.76 21.14 C4Norm 2500 0.000168686 22.10 21.18 23.64 I C5Iso 1000 0.000127503 35.92 33.48 37.90 C5Norm j 1000 0.000128252 39.86 37.92 42.66 I I I I Sample Frequency 50 Hz Oven Temperature: 61 C Hydrogen Flow. 38 CC /min Air Flow 200 CC /min I r I I t INSITE, Sperry Inc. I Customer Chromatograph Report I • I Sao I , I To 600 - I 0 W 2 400 - in 'j 1 � 1 200 1 I v 0 0 5 10 15 20 25 30 35 40 45 I Time Since Inject (sec) I Date: Mar 02, 2009 Well: 2 -30B ME -01 Run: 100 I Mode: Calibration Logger: I Component Concentration (ppm) Cal. Factor Ret. Time (s) L.lim (s) R.Lim (s) Cl 10000 0.000669398 9.92 9.42 10.86 C2 4980 0.000334620 11.40 10.90 13.24 C3 5000 0.000217469 14.54 13.68 18.10 I C4Iso 2500 0.000170388 20.12 18.76 21.14 C4Norm 2500 0.000166630 22.10 21.16 23.62 CSlso 1000 0.000125745 35.98 33.66 37.98 C5Norm 1000 0.000125963 39.94 38.00 42.90 I I I I Sample Frequency: 50 Hz Oven Temperature: 61 C Hydrogen Flow: 38 CC /min Air Flow: 200 CC /min I • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format.
