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167-051
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, April 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC C34-23 MGS C34-23 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/17/2023 C34-23 50-733-20041-00-00 167-051-0 W SPT 7999 1670510 2000 750 750 750 750 65 68 68 68 4YRTST P Sully Sullivan 3/10/2023 Swapping over from injector c23-23, C34-23 last MIT was 5/4/2018 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MGS C34-23 Inspection Date: Tubing OA Packer Depth 560 2154 2153 2152IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230317160830 BBL Pumped:0.6 BBL Returned:1.3 Monday, April 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.04.17 14:28:31 -08'00' • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg f DATE: Tuesday,May 08,2018 �r �I { g SUBJECT: Mechanical Integrity Tests P.I.Supervisor (( 11 HILCORP ALASKA LLC C34-23 FROM: Adam Earl MGS C34-23 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MGS C34-23 API Well Number 50-733-20041-00-00 Inspector Name: Adam Earl Permit Number: 167-051-0 Inspection Date: 5/4/2018 Insp Num: mitAGE180507153625 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -- ------1 H Type Testi SPT 'TVD 7999 Tubing3550 3550 3550 ' 3550 ' Well 04-23 vliType InI w / 7999 _- 3550 2000 IA 45 2180 2170 - 2165 - BBL Returned OA PTD i 1670510 BBL Pumped: o.a ,, est sI 0 5 ✓ 75 100 - 100 100 Interval 4YRTST . P/F 1P Notes: MIT/IA ,/ SCANNED . . . Tuesday,May 08,2018 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 16, 2014 TO: Jim Regg P.I. Supervisor ' `eeo 71ZI (4 SUBJECT: Mechanical Integrity Tests XTO ENERGY INC C34-23 FROM: Chuck Scheve MGS C34-23 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry �1%� NON-CONFIDENT] A L Comm Well Name MGS C34-23 API Well Number 50-733-20041-00-00 Permit Number: 167-051-0 Insp Num: mitCS140605072954 Rel Insp Num: Inspector Name: Chuck Scheve Inspection Date: 5/27/2014 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ell C34-23 Type Inj W' TVD 7999 IA 26 2206 I 2197 2195 TD 1670510 Type Test SPT Test psi' 2000 OA 74 94 96 96 Interval 4YRTST – — ' P/F P Tubing 3400 3400 ' 3400 3400 Notes: CrAjIM OCT 03 20 Wednesday, July 16, 2014 Page 1 of 1 MEMORANDUM TO: Jim Regg ~ j+i'~~it.~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 12, 2010 SUBJECT: Mechanical Integrity Tests XTO ENERGY INC C34-23 MGS C34-23 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~l~'~~ Comm Well Name: MGS C34-23 Insp Num: mitCSloo5o8080305 Rel Insp Num: API Well Number: 50-733-20041-00-00 Permit Number: 167-051-0 Inspector Name: Chuck Scheve Inspection Date: 5/3/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ c3a-z3 Type Inj. W 'I'`/D 7999 `~ IA 100 2175 2175 2175 P.T.D 116°5 ° TypeTest ~ SPT Test psi 1999 OA o 0 0 0 Interval 4YRTST p~ P r/ Tubing 3400 3400 3400 3400 Notes: ., r, r~ .... L a .:.Sfv Wednesday, May 12, 2010 Page 1 of 1 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg _;' . I_I"' P.I. Supervisor ¡{e?¿- Þ, '?, (Ap DATE: Thursday, May 25,2006 SUBJECT: Mechanical Integrity Tests XTO ENERGY INC C34-23 MGS C34-23 o~\ \~~~ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :JE;;?-- Comm NON-CONFIDENTIAL Well Name: MGS C34-23 API Well Number 50-733-20041-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060524151417 Permit Number: 167-051-0 Inspection Date: 5/22/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. C34-23 ¡Type Inj. i w IA I Well TVD 7999 i 0 2080 2060 2060 I , i I -- P.T. 1670510 ITypeTest ! SPT Test psi 1999_75 OA 25 40 , 50 50 i i -+--- Interval 4YRTST P/F P Tubing ¡ 3500 3500 3500 3500 , Notes Test was performed in a safe and proficient manner by XTO personnel. _.~"",,-I~~'!~t:.t.: 'J¡vl¡ ,.- < Thursday, May 25, 2006 Page 1 of 1 Noveraber-2002 (223-23 ACT DATE & NOTI~ INJ [NJ ANNU 01 -Nov-2002 02-Nov*2002 03-Nov-2002 ' 04-Nov-2002 05-Nov-2002 06-Nov-2002 07-Nov-2002 08-Nov-2002 09-Nov-2002 10-Nov-2002 11-Nov-2002 12-Nov-2002 13-Nov-2002 14-Nov-2002 1854 3450 1848 3450 1764 3450 1759 3450 [769 3450 1814 3450 1823 3450 1851 3450 1861 3450 1815 3450 1818 3450 1793 3450 1750 34-50 1758 3450 WATER INIECTION REPORT PLATFORM C ,--- h [NJ [NJ ANNU 0 50 51( 0 50 51( 0 50 51( 0 50 51( 0 50 51( 0 50 51( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56( 0 50 56~ 0 50 560 0 50 560 [NJ [NJ ANNU 398 3475 355( 399 3500 355( 389 3500 350( 388 3450 350( 386 3450 350( 393 34OO 345( 396 3550 350( 402 3550 350( 402 3550 350( 396 3500 350( 394 3500 350( 397 3500 345( 398 3500 3451) 66 1350 1350 C34-23 ACT INJ [NJ A~NU 587 3450 573 3450 496 3400 498 34~0 · 502 3400 533 3400 599 3450 634 3450 597 3450 605 3450 662 3450 667 3450 62O 345O 670 3450 C'23-26 ACT [NJ [NJ ANNU 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 0 0 0 C41-26 ACT [NJ [NI ANNU 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 0 0 0 [NJ INJ ANNU 0 0 55~ 0 0 55C 0 0 55C 0 0 55~ 0 0 55£ 0 0 575 0 0 55~ 0 0 55C 0 0 55( 0 0 55( 0 0 55( 0 0 55( 0 0 55( 0 0 55( 15-Nov-2002 16-Nov-2002 17-Nov-2002 18-Nov-2002 19-Nov-2002 20-Nov-2002 21-Nov-2002 22-Nov-2002 23-Nov-2002 24-Nov-2002 25-Nov-2002 26-Nov-2002 27-Nov-2002 28-Nov-2002 29-Nov-2002 30-Nov-2002 TOTAL MAXIMUM AVERAGE #DAYS 1763 3450 1751 3450 1707 3450 1716 3450 1722 3450 1722 3450 1732 3450 1704 3450 1706 3450 1729 3475 1709 3475 1703 3475 1700 3475 1704 3450 1675 3450 1686 3450 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 510 0 50 510 0 50 510 0 50 510 0 50 510 0 50 51{] 0 50 51{] 0 70 56O 0 70 56~ 0 70 56~ 52,706 3,475 1,757 3,453 30 0 70 560 0 52 538 0 0 1100 1100 0 1050 1050 0 1050 1050 0 1000 t000 0 1000 1000 0 1000 1000 440 3500 3475 421 3500 3475 418 3500 3450 421 3500 3475 397 3500 3475 413 3500 3475 411 3500 3475 409 3450 345{] 403 3450 345~ 404 3450 345~3 9,341 3,550 3,550 311 2,928 2,922 24 566 3450 494 3450 555 3450 583 3450 583 3450 604 3450 634 3500 631 3500 697 3450 682 3500 665 3500 683 3450 673 3475 687 3450 714 3450 715 3450 18,409 3,500 614 3,451 30 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 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 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 55( 0 55( 0 55( 0 55( 0 55( 0 55( 0 55( 0 55( 0 55O 0 550 0 550I 0 575[ 0 550i o 55oi O 5001 0 5501 0 575' 0 550 C24A-14 ACT INJ l~J ANN! 369 4450 370 4450 373 4450 442 4550 421 4550 407 4525 416 4550 412 4550 412 4550 405 4560 380 456O 389 455O 407 4550 403 4500 395 4500 4OO 45OO 4O4 4500 402 4450 387 4450 396 4450 399 4450 394 4450 385 4450 401 4500 381 4500 388 45OO 369 4500 357 4450 362 4450 387 4450 11,813 4,560 394 4,497 3O 12/12/2002 C41-23 shut in due to annular communication problem. WATER INJECTION REPORT PLATFORM C September-2002 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A-14 ACT ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES IBJ INJ ANNU INJ INJ ANNU INJ INl ANNU INJ ][NJ ANNU INJ INJ ANNUi INJ IFil ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNI. 01-$ep-2002 1844 3475 30 0 50 510 415 3550 350( 833 3550 125 0 0 0 0 730 600 0 0 55(] 0 0 0 400 4450 5! 02-Sep-2002 1859 3475 350 50 500 417 3550 350( 880 3550 125 0 0 0 0 730 60(3 0 0 55G 0 0 0 412 4500 03-8ep-2002 1861 3500 35 0 50 510 417 3550 350( 917 3550 13C 0 0 0 0 730 60~ 0 0 55(3 0 0 (3 417 4500 5 04-$ep-2002 1865 3500 30 0 50 510 415 3550 350( 909 3550 125 0 0 0 0 730 60~ 0 0 55(3 0 0 (3 430 4525 5 05-8ep-2002 1863 3500 30 0 50 510 416 3550 350( 862 3550 125 0 0 0 0 730 60~ 0 0 55{3 0 0 (3 424 4525 5 06-8ep-2002 1864 3500 3(3 0 50 510 414 3550 350( 790 3550 125 0 ' 0 0 0 730 60(3 0 0 575 0 0 (3 432 4525 5 07-$ep-2002 1860 3500 25 0 50 51(3 415 3500 350C~ 783 3500 11£ 0 0 0 0 730 60~ 0 0 55£ 0 0 (3 415 4500 0 08-Sep-2002 1861 3500 25 0 50 510 412 3500 3500 773 3500 11£ 0 0 0 0 730 60(~ 0 0 55C 0 0 C 402 4500 0 09-Sep-2002 1868 3500 25 0 50 51(3 413 3500 3500 755 3500 I1£ 0 0 0 0 730 60~ 0 0 55C 0 0 {3 391 4500 0 10-Sep-2002 1841 3500 250 50 51(3 410 3500 3500 766 3500 11£ 0 0 0 0 730 60~ 0 0 55£ 0 0 C 402 4500 0 1 l-Sep-2002 1853 3500 250 50 51(3 412 3500 3500 774 3500 t1£ 0 0 0 0 · 730 60~ 0 0 55C 0 0 C 394 4500 12-S¢p-2002 1841 3500 25 0 40 555 408 3500 3500 746 3500 I0.~ 0 0 0 0 730 575 0 0 55£ 0 0 389 4450 4 13-Sep-2002 1836 3500 23 0 40 555 407 3500 3500 787 3450 10.~ 0 0 0 0 730 575 0 0 55( 0 0 396 4450 4 14-Sep-2002 1850 3500 25 0 40 56~ 408 3500 3500 769 3500 10~ 0 0 0 0 735 575 0 0 55£ 0 0 391 4450 5 15-$ep-2002 1868 3500 250 50 56{3 406 3500 3525 826 3500 10~ 0 0 0 0 735 575 0 0 55( 0 0 396 4500 4 16-8ep-2002 1870 3500 270 80 56( ,:[05 3500 3500 794 3500 11( 0 0 (3 0 735 575 0 0 55£ 0 0 398 4500 5 l 7-8ep-2002 1845 3500 250 60 56~ 399 3500 3525 688 3500 11£ 0 0 (3 0 735 575 0 0 55( 0 0 408 4500 5 18-$ep-2002 1864 3500 25 0 50 56~ 400 3500 3500 666 3500 11( 0 0 (3 0 735 575 0 0 55( 0 0 401 4500 5 19-Sep~2002 1693 3500 25 0 50 56( 372 3500 3500 626 3500 10~ 0 0 (3 0 735 575 0 0 55( 0 0 368 4500 20-$ep-2002 1768 3450 25 0 50 56( 388 3450 3450 678 3450 10." 0 0 (3 0 735 575 0 0 55£ 0 0 391 4500 2 l-Sep-2002 1777 3450 25 0 50 56{3 131 3450 3450 601 3450 10X 0 0 {3 0 735 57~ 0 0 55( 0 0 391 4500 C 22-Sep-2002 1767 3450 25 0 50 56( 0 1100 Il00 697 3450 102 0 0 {3 0 735 57.~ 0 0 55( 0 0 393 4500 23-$ep-2002 1765 3450 25 0 50 56( 0 1050 1050 760 3450 10." 0 0 (3 0 735 57.~ 0 0 5501 0 0 394 4500 24-Sep-2002 1778 3450 25 0 50 56( 0 1000 1000 801 3450 102 0 0 ~ 0 735 57.~ 0 0 55( 0 0 394 4500 {3 25-Sep-2002 1778 3450 0 50 56( 173 3500 3500 597 3450 ~ 0 0 {3 0 735 57.~ 0 0 5501 0 0 380 4450 {3 26-Sep-2002 1798 3450 0 50 56( 419 3500 3460 605 3450 25l 0 0 {3 0 735 60( 0 0 575! 0 0 360 4~.50 27-S¢p-2002 1804 3450 0 50 56( 413 3500 3460 632 3450 25! 0 0 {3 0 735 60( 0 0 550 0 0 360 4450 28-Sep-2002 1827 3475 0 50 555 417 3550 3475 660 3475 110 0 0 {3 0 735 60( 0 0 550 0 0 389 4500 29-S¢p.2002 1674 3450 0 50 55( 393 3500 3475 621 3500 90 0 0 {3 0 730 60( 0 0 500 0 0 416 4550 30-Sep-2002 1429 3450 0 50 51£ 328 3550 3475 600 3500 60 0 0 (~0 730 60( 0 0 550 0 0 342 4525 TOTAL 5¢,271 0 10,423 22,196 0 0 0 0 11,876 MAXIMUM 3,500 3580 56~ 3,550 3,525 3,550 1300 0 735 60( 0 575 0 4,550 5 AVERAGE 1,809 3,481 21 0 50 539 347 3,265 3,248 740 3,494 100 0 0 (3 0 733 58~ 0 0 550 0 0396 4,493 3 # DAYS 30 0 27 30 0 0 0 0 30 10/14/2002 241-23 shut in due to annular communication problem. 224A-23 shut in for field study and evaluation per Doug Marshall. SCANNED MAR i 0 2003 I WATER INJECTION REPORT PLATFORM C C23~~3 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A-14 June-2002 ACT INJ ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES INJ ANNU INJ INJ ANNU 1NJ INJ ANNU IiNJ IN'J AHNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU, INJ INJ AHNI. INJ INJ ANNU 01 -Jun-2002 1770 3500 ( 0 0 6i5; 371 3450 3450 0 0 0 0 0 ( 0 440 250 1,080 1,800 550i0 0 0] 191 3500 0 02-Jun-2002 1776 35~)0 ( 0 0 6151 373 3450 3450 0 0 G 0 0 ( 0 440 250 325 1,800 5501 0 0 175 3500 0 03-$un-2002 1760 35,00 ( 0 0 615, 369 3450 3450 0 0 0 0 0 C 0 440 250 220 1,800 5501 0 0 203 3500 0 04-$un-2002 1764 3450 ( 0 0 615i 373 3425 3425 0 0 0 0 0 C 0 440 250 0 0 550] 0 0 203 3500 05-Jun-2002 1376 34~0 ( 0 0 615 291 3425 3425 0 0 0 0 0 ( 0 440 250 0 0 55( 0 0 155 3500 06-.Iun-2002 1198 34~ ( 0 0 615~ 242 3350 3400 0 0 0 0 0 0 0 570 400 0 0 57! 0 0 141 3500 07-Jun-2002 970 34~30 ( 0 0 615i 219 3350 3400 0 0 0 0 0 13 0 570 400 0 0 55( 0 0 1181 3500 08-Jun-2002 612 3450 ( 0 0 615] 398 3400 3450 0 0 0 0 0 (] 0 590 400 272 1,900 55( 0 0 2251 3500 09-Jun-2002 1416 34~0 ( 0 0 611 291 3400 3450 0 0 0 0 0 0 0 600 400 377 1,800 55( 0 0 152! 3500 10-Jun-2002 1950 34~50 ( 0 0 6l( 394 3425 3475 229 3500 0 0 0 0 0 600 400 0 0 55£ 0 0 203~ 3500 I l-Jun-2002 1876 3450 C 0 0 61( 386 3450 3500 410 3500 0 0 0 0 0 610 450 0 0 55( 0 0 222'~ 3500 12-Jun-2002 1849 3500 ( 0 0 611 387 3450 3500 370 3500 0 0 0 0 0 620 450 372 1,800 55( 0 0 2051 3500 13-Jun-2002 1846 3500 ( 0 0 611382 3450 3500 430 3500 0 0 0 0 0 620 450686 1,800 55( 0 0 194! 3500 14-Jun-2002 1858 3500 0 0 0 611 382 3450 3500 484 3500 0 0 0 0 0 620 450 432 1,800 55C 0 0 432 4100 15-Jun-2002 1864 35~0 C 0 0 611 384 3450 3500 619 3500 0 0 0 0 0 620 450 0 0 55( 0 0 403 4500 16-Jun-2002 1865 3500 0 0 0 611384 3450 3500 634 3500 0 0 0 0 0 620 450393 1,$00 55( 0 0 457 4500 IT-Jun-2002 1877 3500 0 0 0 611 383 3450 3500 636 3500 0 0 0 0 0 620 45( 0 0 55( 0 0 438 4500 18-Jun-20G2 1895 3500 0 0 0 61(384 3450 3500 625 3500 0 0 0 0 0 620 45(386 1,850 55( 0 0 341 4450 19-Jun-2002 1864 3500 0 0 0 61( 380 3450 3500 661 3500 0 0 0 0 0 620 450 312 2,100 5513 0 0 352 4450 20-Jun-2002 1885 3500 0 0 0 61.~ 381 3475 3500 693 3500 0 0 0 0 0 660 50(0 0 55(3 0 0 347 4450 21 -Jun-2002 1824 3500 0 0 0 61.~ 374 3475 3500 579 3500 0 0 0 0 0 665 50(340 1,900 550 0 0 317 4500 22-Jun-2002 1848 35b0 0 0 0 61~390 3450 3500 470 3500 0 0 0 0 0 720 50(0 0 550 0 0 (30t 4400 23-Jun-2002 1874 35~!O 0 0 60 61.~ 386 3500 350~ 491 3500 0 0 0 0 0 670 50( 0 0 550 0 0 ( 314 4400 24-Jun-2002 1757 3400 0 0 60 62( 370 3400 345( 388 3425 0 0 0 0 0 675 50( 354 1,900 550 0 0 ( 342 4500 25-Jun-2002 1843 3450 0 0 60 62(379 3450 350( 485 3500 0 0 0 0 0 725 50(0 0 550 0 0 (346 4500 ( 26-Jun~2002 1867 35® 0 0 60 615 371 3450 350( 568 3500 0 0 0 0 0 680 50( 332 1,900 575 0 0 ( 358 4500 ( 27-Jun-2002 1923 34~50 0 0 60 615 373 3500 350( 559 3500 0 0 0 0 0 680 50( 360 2,000 550 0 0 0 336 4500 ( 28-Jun-2002 1922 34~50 0 0 60 615365 3500 350( 557 3500 0 0 0 0 0 680 50(0 0 550 0 0 00 2800 ( 29-Jun-2002 1916 34~50 0 0 60 615 362 3500 350( 524 3500 0 0 0 0 0 680 50( 0 0 500 0 0 0 19 2800 (~ 30-Jun-2002 1903 34~50 0 0 60 61.~ 359 3500 350( 547 3500 0 0 0 0 0 680 50(353 2,000 550 0 0 0526 4400 0 TOTAL 51,948 ~ 0 10,883 10,959 0 0 6,594 0 8,016 MAXIMUM 3,51)0 0 60 620 3,500 3,50( 3,500 0i 0 01 725 50~ 2,100 575 0 0 4,500 0 AVERAGE 1,732 3,4172 0 0 16 614 363 3,446 3,47~ 365 2,448 0 0 0 0 0 607 427 220 998 550 0 0 0 267 3,925 0 # DAYS 30 ~ 0 30 20 0 0 16 0 29 07/I 1/2002 1-23 shut m due to annular communication problem. ] ~24A-23 shut in for field study and cvaluatlon per Dou- Marshall. SCANNED MAR I 0 2003 WATER INJECTION REPORT PLATFORM C October-2002 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-14 ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES INS INJ ANNU INJ INJ ANNU INJ INJ ANNU II~J l~J ANNU INJ INJ ANNU INS INJ ANNU IN.! INJ ANNU INJ 13/J 01-Oct-2002 1808 3450 (~ 0 50 51(~ 411 3500 345( 669 3500 8C 0 0 (~ 0 0 ¢ 0 0 55(3 410 4500 02-Oct-2002 1809 3475I 0 50 56( 408 3525 347.~ 637 3500 6( 0 0~ 0 0 £ 0 0 55(~ 192 3500 03-Oct-2002 1808 3~75 0 50 56( 405 3525 347.~ 617 3500 6( 0 0 ~ 0 0 £ 0 0 55(3 337 4500 04-Oct-2002 1815 3475 (~ 0 50 56( 404 3525 347~ 688 3500 6( 0 0 (~ 0 0 £ 0 0 55(3 428 4500 05-Oct-2002 1809 3475 0 0 50 56( 395 3525 347.~ 650 3500 6( 0 0 0 0 0 £ 0 0 55(3 413 4500 06-Oct-2002 1795 3475 ~ 0 50 56( 404 3525 347.~ 628 3500 6( 0 0 0 0 0 £ 0 0 575 397 4500 07-Oct-2002 1813 3475 0 0 50 56( 405 3525 347~ 687 3500 6( 0 0 0 0 0 £ 0 0 55(3 417 4500 08-Oct-2002 1824 3475 0 0 50 56( 405 3525 347.~ 631 3500 6( 0 0 0 0 0 £ 0 0 55(3 402 4500 09-Oct-2002 1803 3475 0 0 50 56( 400 3525 347~ 629 3500 6( 0 0 0 0 0 0 0 55(3 403 4500 10-Oct-2002 1756 3475 0 0 50 56( 398 3525 347.~ 548 3500 6( 0 0 0 0 0 0 0 55(3 425 4500 11-Oct-2002 1755 3475 0 0 50 56( 399 3525 347.~ 546 3500 6( 0 0 0 0 0 0 0 55(3 413 4500 12-Oct-2002 1776 3475 0 0 50 56( 403 3525 347.~ 579 3500 6( 0 0 0 0 0 { 0 0 55(3 381 4500 13-Oct-2002 1771 3450 0 0 50 56( 400 3500 350( 640 3450 £ 0 0 0 0 0 0 0 55(3 379 4500 14-Oct-2002 1830 3450 0 0 50 56( 410 3500 350( 654 3450 £ 0 0 0 0 0 £ 0 0 55(3 405 4500 15-Oct-2002 1775 3450 0 0 50 56( 394 3500 350( 574 3450 £ 0 0 0 0 0 0 0 55(3 407 4575 16-Oct-2002 1807 3450 0 0 50 56( 401 3500 350( 558 3450 £ 0 0 0 0 0 0 0 55~ 387 4575 17-Oct-2002 1820 3450 0 0 50 56( 402 3500 350( 565 3450 0 0 0 0 0 0 0 55(3 412 4550 18-Oct-2002 1827 3450 0 0 50 56( 402 3500 350( 491 3450 £ 0 0 0 0 0 0 0 55(3 412 4550 19-Oct-2002 1836 3450 0 0 50 56( 406 3500 350( 522 3450 £ 0 0 0 0 0 0 0 55(3 419 4550 20-Oct-2002 1808 3450 0 0 50 56( 400 3500 350( 556 3450 £ 0 0 0 0 0 0 0 5.5~ 415 4550 21-Oct-2002 1827 3450 0 0 50 56( 405 3500 350( 584 3450 0 0 0 0 0 0 0 55(3 412 4550 22-Oct-2002 1799 3450 0 0 50 56( 400 3500 350( 572 3450 £ 0 0 0 0 0 0 0 55~ 410 4550 23-Oct-2002 1832 3450 0 0 50 56( 405 3500 350( 546 3450 0 0 0 0 0 0 0 55(3 437 4550 24-Oct-2002 1802 3460 0 0 80 52( 402 3500 347~ 551 3500 £ 0 0 0 0 0 0 0 55(3 409 4600 25-Oct-2002 1812 3460 0 0 80 51( 407 3500 347.~595 3500 £ 0 0 0 0 . 0 0 0 55(3 418 4600 26-Oct-2002 1708 3460 0 0 80 51( 389 3500 347.~ 543 3450 0 0 0 0 0 0 0 575 388 4500 27-Oct-2002 1874 3450 0 0 50 51( 410 3500 350( 628 3475 £ 0 0 0 0 0 0 0 55(3 405 4500 28-Oct-2002 1784 3475 0 0 50 51.~ 389 3500 345( 699 3450 0 0 0 0 0 0 0 55(3 373 4500 29-Oct-2002 1810 3460 0 0 50 51( 390 3500 347.~ 579 3500 £ 0 0 0 0 0 £ 0 0 50~ 382 4500 30-Oct-2002 1846 3460 0 0 50 51( 397 3500 347.~ 615 3475 0 0 0 0 0 0 0 55(3 393 4500 3 !-Oct-2002 1851 3450 0 0 50 51£ 397 3500 350( 630 3450 0 0 0 0 50(] 39~ 4450 TOTAL 55,990 0 12,443 18,611 0 0 0 12,275 MAXIMUM 3,475 080 56( 3,525 3,50( 3,500 8(3 0 0 0 (3 0 575 4,600 AVERAGE 1,806 3,461 0 0 53 54~ 401 3,509 3,484 600 3,476 24 0 0 0 0 0 (3 0 0 548 396 4,489 #DAYS 31 0 31 31 0 0 0 31 11/12/2002 C41-23 shut in due to annular communication problem. SCANNED i 0 ?.003 WATER INJECTION REPORT PLATFORM C August-2002 C23-23 C41-23 C24-23 1234-23 C23-26 ACT ACT ACT ACT ACT INJ INJ ANNU [NJ INJ ANN1 [NJ [NJ ANNU [N1 1NJ ANNU [NJ [NJ ANN1 DATE & NOTES 0 l-Aug-2002 02-Aug-2002 03-Aug-2002 04-Aug-2002 05-Aug-2002 06-Aug-2002 07-Aug-2002 08-Aug-2002 09-Aug-2002 10-Aug-2002 I 1-Aug-2002 12-Aug-2002 13-Aug-2002 14-Aug-2002 15-Aug-2002 16-Aug-2002 17-Aug-2002 18-Aug-2002 19-Aug-2002 20-Aug-2002 21 -Aug-2002 22-Aug-2002 965 2500 62 1985 3500 22 1919 3500 3( 1897 3500 3£ 1865 3500 3~ 1850 3500 35 1880 3500 28 1871 3500 28 0 80 551 0 70 55{ 0 7O 55( 0 60 551 0 60 551 0 60 55( 0 60 55( 0 60 551 198 1250 1250 408 3500 35OO 405 3500 3525 404 3500 3550 400 3500 3500 298 3500 3550 0 0 1150 0 0 1150 481 1950 10 860 3500 10 959 3500 10 927 3500 10 855 3500 10 865 3500 10 862 3500 10 840 3500 10 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 C44-14RD C24A-23 ACT ACT ACT [NJ INJ ANNU [NJ INJ ANNU [NJ [NJ ANN[. 0 720 55( 0 720 57~ 0 725 57: 0 725 57! 0 725 57! 0 725 57~ 0 725 57: 0 725 57~ 454 2,050 550 409 2,200 550 0 0 550 390 1,950 550 0 0 550 300 1,800 575 0 0 550 0 0 550 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1867 3500 1863 3500 1826 3500 1852 3500 1867 3500 1852 3500 1870 3500 1854 3475 1812 3500 1808 3475 1763 3500 1786 345O 1810 3450 1817 3475 28 0 60 551 28 0 60 551 28 0 60 55( 28 0 60 55( 28 0 60 55( 28 0 60 55( 12 0 80 56( 12 0 6O 55~ 15 0 80 56( 41 0 70 56( 45 0 50 55~ 4( 0 50 55~ 37 0 50 55~ 3~ 0 50 55~ 0 0 1150 0 0 1150 0 0 1150 0 0 1150 0 0 1150 0 0 1150 0 0 975 0 0 950 32 3500 950 303 3500 3125 326 3500 3150 390 3500 3500 391 3500 3500 390 3500 3500 809 3500 10 670 3500 10 592 3500 10 573 3500 10 614 3500 I0 660 3500 10 660 3500 10 640 3500 10 622 3500 10 870 3450 10 793 3450 10 754 3450 10 804 3400 10 875 3475 10 0 725 57~ 0 725 57~ 0 725 575 0 ' 725 57f 0 725 57~ 0 725 57~ 0 725 57~ 0 725 57~ 0 725 57~ 0 725 57~ 0 725 57~ 0 725 57~ 0 725 575 0 725 57~ 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55( 0 0 55( 0 0 55( 0 0 55( 0 0 55( 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 0 0 0 C24A-14 ACT INJ [NJ ANNU 470 4450 503 4600 485 4600 463 4650 471 4700 449 4700 432 4650 350 4650 407 4650 406 4450 392 4450 410 4450 411 4450 418 4450 420 4500 402 4500 411 4500 413 4500 380 4500 389 4400 384 4400 390 4400 23-Aug-2002 24-Aug-2002 25-Aug-2002 26-Aug-2002 27-Aug-2002 28-Aug-2002 29-Aug-2002 30-Aug-2002 3 l-Au;e-2002 TOTAL MAXIMUM AVERAGE # DAYS 1811 3475 1764 3475 1782 3475 1785 3450 1787 3450 1734 3475 1528 3475 1793 3475 1830 3475 55,693 3,500 1,797 3,453 31 0 50 55~ 0 50 55~ 0 50 55~ 0 50 55~ 0 50 55~ 0 50 55~ 0 50 55~ 0 50 50~ 0 50 51C 0 62 80 56~ 26 0 59 55C 0 340 3500 3500 0 0 3500 0 0 3500 198 3500 1000 265 3475 3475 145 3500 3350 363 3500 3350 417 3550 350~ 417 3550 35001 6,090 3,550 3,55( 196 2,075 2,46.~ 19 835 3475 10 593 3475 10 625 3475 10 682 3450 10 864 3450 10 852 3450 10 724 3450 10 770 3550 I0 848 3550 10 23,378 3,550 10 754 3,435 10 31 09/16~-002 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 725 575 0 725 57~ 0 725 57~ 0 725 575 0 725 575 0 725 575 0 725 575 0 730 575 0 730 60( 0 730 600 0 725 575 0 0 0 55( 0 0 55C 0 0 55( 0 0 57.~ 0 0 55( 0 0 55( 0 0 50( 0 0 55( 0 0 55C 1,553 2,200 575 50 258 55C 4 0 384 4400 0 391 4400 0 401 4400 0 421 4400 0 407 4400 0 372 4500 0 380 4500 0 385 4400 0 399 4450 12,796 0 4,700 0 413 4,498 31 C41-23 shut in due to annular communication problem. C24A-23 shut ia for field study and evaluation per Doug Marshall. SCANNED MAR 1 0 2003 MEMORANDUM State of AlaSka Alaska Oil and Gas Conservation Commission THRU: Tom MaUnder ~l'~t~'~ ~.O'~ ~ Petroleum Engineer TO: Cammy O, Taylor £~-'~ DATE: June 13, 2002 Chair SUBJECT: Mechanical Integrity Tests Cross Timbers Operating Platform "C" C34-23 FROM: Lou Grimaldi Petroleum Inspector Middle Ground Shoal Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. . .,W. oIII C34~23 I Typelnj. I S I T.V.D. J I Tubing [ 3500 ] 3500 [ 3500 I 3500 I lntervall 4 P.T.D.I 167-051 ITypetestl P ITestpsiJ 2000 JCasing, .I 10. I 2000 I 1990 J 1990 I P/F. I.-P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) TeSt's Details I was onboard for SVS tests and was requested .to witness the four year MIT on this well. Tom Reese conducted the test today: The well passed its MIT. M.I.T.'s performed: .one Attachments: None Number of Failures: None Total Time during tests: t hour cc: Doug Marshall (XTO) MIT report form 5/12/00 L.G. MIT MGS C34-23 6~13-02 LG.xls 7/13/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing After casing Plugging Perforate. Repair well X Other . 2. Name of Operator 3. Address 3000 N. Garfield, Ste 175, Midla~z~, TX 79705 5. Type of Well: Development Exploratory Stratigraphic S~rvice 4. Location of well atsurface Platform "C" Leg 1 Conductor 6 535.88'N & 1597.22'W frcm SE Oorr~ar of Sec. 23, T8N, R13W, ~M At top of productive interval 624.6'N & 1832'W frcm SE O~rner of Sec. 23, T8N, R13W, SM At effective depth At total depth 669.6'N & 1907'W fz'x:at SE ~ cE Sec. 23, T8N, R13W, SM 6. Datum elevation (DF or KB) 35' KB 7. Unit or Property name 8. Well number C34-23 feet 9. Permit number/approval number ~7-51 10. APl number 50- 733-20041-00 11. Field/Pool ~/"E", "F" & "G" Pcx:)ls 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 2007' 9545' measured 8097-9419' truevertical 9642 feet Plugs (measured) 9633 feet 9440 feet Junk (measured) 9432 feet Size Cemented Measured depth True vertical depth 10-3/4", 40.5~, J-55 1850 S~ 2007' 2007 ' 7",26-29#, N-80 1100 S~ 95~5' 9536' RECEIVED 8092'-9412' (12 intervals) JUN 1 ZOO2 Tubing (size, grade, and measured depth) 2-7/8" 7.9#. ~S-6 L-80 0-8663' Packers and SSSV (type and measure(] depth) 7" S~-3 Pe.l::at ~ @ 8004' & ]~aker 7" ~ ~ @ 8637' 13. Stimulation or cement squeeze summary Intervals treated (measured) 8698 - 9419' Treatment description including volumes used and final pressure S~ot 1220 gal 1~ BCl over [~rfs. Soak 30 tab, utes a~d reverse~ out acid. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation 1536 3050 3100 Subsequent to operation 634 0 3500 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service ~=tive ~ector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Sr. Operations ~giaeet - 44 - ORIGINAL Date 6/19/2002 SUBMIT IN DUPLICATE ~~E ~E BGY MGS C34-23 WIW Cook Inlet, Alaska Leg 1, Conductor 6 APl No.: 50-733-20041 Spud: 9-13-67 24' Conductor @ 370' Surf Csg: 10 3/4", 40.5 lb, J55. Set @ 2,007'. Cmt w! 1,850 sx. TOC @ surface w/2 Top Jobs. TOC (CBL) @ +/-6860'. Present Completion PLF 6-18-02 KB: 35' Water Depth: 73' MSL Tubing: 2 7/8" 7.9# RTS-6 L80 @ 8,663' Set: 6-1-02 2 7/8" R Nipple (2.188" ID) 9Cr @ 335' 244 Jts 2 7/8" 7.9# L80 RTS-6 Tbg 2 7/8" R Nipple (2.188" ID) 9Cr @ 7,990' 10' Pup Jr. 2 7/8" 7.9# RTS-6 L80 X-Over RTS-6 Box to 2 7/8" 8R Pin @ 8,001' "E" Anchor (80-32) L80 @ 8,002' 7" Baker SB-3 Pkr (84-32) 9Cr @ 8,004' 5' 4-1/2" Millout Ext. LTC 12.6# 9Cr @ 8,009' X-Over 4.5" LTC Box to 2 7/8" RTS-6 Pin 9Cr 10' Pup Jt. 2 7/8" 7.9# RTS-6 L80 2 7/8" R Nipple (2.188" ID) 9Cr @ 8,024' 19 Jts 2 7/8" 7.9# L80 RTS-6 Tbg 10' Pup Jr. 2 7/8" 7.9# RTS-6 L80 @ 8,625' Locator w/6' Bonded Seals (80-32) @ 8,635' 7" Baker DB Pkr (84-32) L80 @ 8,637' ** 4' Sealbore Ext (80-32) 9Cr @ 8,641' X-Over (80-32) Box to 2 7/8" RTS-6 Pin 9Cr 10' Pup Jt. 2 7/8" 7.9# RTS-6 L80 2 7/8" RN Nipple (2.01" ID) 9Cr @ 8,656' 6' Pup Jt. 2 7/8" 7.9# RTS-6 9Cr WL Re-entry Guide @ 8,663' ** Adjusted DB packer depth by 14'. DB Packer was set on drill pipe & sealbore was RIH on tbg that stung in 14' deeper. GN-GO: 8097'-8099' GN-GO: 8106'-8114' GR-GS: 8407'-8439' Prod Csg: 7" N80 set @ 9,545'. Surface - 124':29# 124 - 7,453': 26# 7,453 - 9,545': 29# Cmt w/1100 sx. HC-HD: 8698'-8728' HE-HF: 8799'-8844' HI-HK: 8908'-8932' HI-HK: 8939'-8949' PBTD: 9,440' MD (9,432' TVD) TD: 9,642' MD (9,633' TVD) HK-HN: 8966'-9088' H N-H R: 9103'-9164' HN-HR: 9172'-9250' HR-HZ: 9268'-9278' HR-HZ: 9294'-9419' X.TO Energy - Midland District MonthJz~Report ~----, Page 1 of 8 Midland Monthly Report IIMIDDLEGROUND SHOAL C II Well # 34-23 Objective: Repair Tbg and/or Pkr Lk & RWTI AFE: 1st Rept: 5/1/02 2OO543 05/01/2002 First Report for AFE #200543 to repair tbg and/or packer leak & RWTI. Cleaned pits & prep to skid rig. DWC: $4,551 CWC: $4,551 DMC: $0 CMC: $0 5/2/02 Cleaned pits. Prep rig for move. Skidded rig over MGS C34-23 wellbore. Secured rig. Organized decks for CTU. Moved BOP's across cellar to make room for CTU riser. Installed hand rails. Unloading CTU, tnk, etc fr boat. Spotting same. Contd cleanng pits. DWC: $24,370 CWC: $28,921 DMC: $0 CMC: $0 5/3/02 Fin unloading CTU fr boat. RU CTU. Fin cleaning pits. RU prod return tnk. Set CT BOP's. Filled CT w/FIW. Press tstd BOP'S to 3,000 psig, tstd okay. RD tst assy. MU milling assy. Held safety meeting. RIH w/Baker 2.71" dual bladed metal muncher mill, x-over, Baker 2.18" motor, circ sub, 0.5" ball drop, Baker hydraulic disconnect, 0.625" ball drop, dual flapper valve, external slip connector. Pull tstd to 16K (tot BHA 18.07") on 1-3/4" CT. Tagged solid btm @ 8,914' (CTM). Circ hole. TOH w/CT, pmpg 1.5 BPM. DWC: $38,678 CWC: $67,599 DMC: $0 CMC: $0 · . 5/4/O2 Fin pmpg CT out of hole. RD injector head. Spotted & RU APRS WL. Press tstd lubricator to 1,500 psig, tstd okay. RIH w/2-5/8" jet cutter. Tight spot fr/6,000'-6,050'. Stopped @ lwr GLM (8,914'). Cut tbg @ 8,883'. POOH. Made up 2.70" jet cutter. Attempted to go thru tbg hanger. No go. Made up 2.70" gauge ring. RIH to 8,810'. Tight spots @ tbg hanger, 6,000' & OS shot pack off @ 8,549'. POOH. Made up 2.70" jet cutter. Worked dn to 1,600'. RU & pmpd jet cutter dn w/15-24 GPM @ 1,500-1,700 psig. Made 2nd cut @ 8,847'. POOH. Tight @ each coupling. Made up 2.70" jet cutter. Pmpd dn & made 3rd cut @ 7,983' POOH w/WL (tight @ each coupling). DWC: $59,000 CWC: $126,599 DMC: $5,839 CMC: $5,839 5/5/02 Fin POOH w/APRS WL. RD WL. RU CTU. RIH w/CT to 8,914'. Pmpg FIW. Chgd over to 11.0 pmpg fluid. Taking returns in prod tnk until kill wt fluid got around, then circ across shakers. POOH circ 1.0 BPM. RD D-S CTU & RU to flow C32-23LW. Set BPV. ND & set out tree (NOTE: threads in top of tbg hanger gone). Set riser & NU BOP' s. DWC: $80,499 CWC: $207,098 DMC: $17,215 CMC: $23,054 5/6/02 Fin NU BOP's. Monitored well (well stable). Pulled BPV. Ran 2-way check. Press tstd riser against blind rams to 500 psig (consulted w/Lou Grimaldi w/AOGCC). Made up spear assy. Ran & speared tbg hanger. Pulled to rig floor. Chgd out hanger. Landed new hanger w/2-way check back in tbg spool. Press tstd BOP' s to 250-5,000 psig. RU to LD tbg. Attempted to dry up tbg w/dry job. Std LD 3-1/2", 9.3#, L-80 tbg. Hole in tbg @ 580'. Had 2,500' of tbg LD @ report time. DWC: $24,020 CWC: $231,118 DMC: $2,327 CMC: $25,381 http ://dor/rept_mr. asp 6/18/2002 XTO Energy - Midland District MonthJ~ed~eport .~--~ Page 2 of 8 5/7/02 Fin LD 3-1/2", 9.34/, L-80, EUE, 8rd tbg. Made up guide, 5-3/4" x 4-3/4" x 3-1/2" hollow mill (3.27'), 5- 3/4" OS dressed w/3-1/2" grapples, 5-3/4" x 4-1/2" ext (3.59'), top sub, bumper sub & jar combo, 12 - 4- 3/4" DC' s. RIH w/81 stds & a single of 3-1/2", 15.50# DP. Worked over fish @ 7,983'. Mixed & pmpd dry job. TOH. LD fish & fishing assy. Recovered 19.58' cut off & 7.43' seal assy. Made up 3-1/4" x 3/4" spear dressed w/4.010" grapple & ext. RIH. Tagged fish (top pkr) @ 7,993'. Worked spear thru pkr. Pulled pkr loose. Mixed & pmpd dry job. Blew dn mud lines. POOH slowly w/fish. DWC: $23,179 CWC: $254,297 DMC: $1,506 CMC: $26,887 5/8/02 Fin TOH. Did not have pkr. Chgd out spear for Baker retrieving tool (6.35'), x-over (1.20'), jar combo (28.94'), 12 - 4-3/4" DC's (370.18'). TIH & tagged top of pkr @7,999'. Latched onto pkr w/retrieving tool. Pkr appeared to be free, but unable to get fish loose. Rel retrieving tool fr pkr. Pmpd dry job. TOH. LD fishing tools. RU APRS WL. RIH w/2-5/8" jet cutter. Cut tbg @ 8,090' (2-1/2 jts below top pkr). POOH w/cutter & RD APRS WL. Made up Baker retrieving tool (6.35'), x-over (1.20'), jar combo (28.94'), 12 - 4- 3/4" DC' s (370.18'). TIH w/fishing assy. Slipped & cut drlg line. Latched onto pkr (appeared to pull free). Pmpd dry job. POOH. Fish @ the rotary @ report time. Total pipe recovered fr well 7,967.68'. Initial recovery above 1st cut was 253 jts, 2 pups, 2 x-nipples. Cut off was 7,948.10'. Fish was a cut off w/seal assy (19.58'). DWC'. $22,859 CWC: $277,156 DMC: $1,851 CMC: $28,738 5/9/02 Fin laying dn (Baker pkr & milled out ext, x-over, 2 jts of 3-1/2" tbg & cut off). Total length 87.49'. MU BHA, 5-3/4" x 4-3/4" x 3-1/2" hollow mill (3.62'), 5-3/4" OS with 3-1/2" grapples (1.55'), ext 3.59', top sub 1.01', jar combo 28.94', 12 DC's (370'), slinger (ACC) 9.70'. TIH to top of fish @ 8,081' DP measurement. Latched onto fish. Worked & jarred on fish. No success. Worked @ releasing OS. Pmpd dry job. TOH. LD OS, MU wash over BHA, 6" x 4-3/4" shoe (2.99'), 5-7/8" x 4-13/16" cutter (3.45'), 15 jts of 5-3/4" x 5" WP (482.56'), 5-3/4" x 2" WO basket (2.86'), 4-3/4" x 2-1/4" bumper sub (10.75'). TIH to 7,100'. Circ DP vol. Repaired wet plug. Fin TIH. Washed & reamed over 3-1/2" tbg fr 8,081'- 8,544' (appeared to tag overshot). Tagged fill @ 8,330' (214' of solid fill). Pmpd sweep & circ bottoms up. Total pipe rec fr well: 8,055.17'. DWC: $29,552 CWC: $306,708 DMC: $1,884 CMC: $30,622 5/10/02 Fin circ btms up w/sweep. Pulled up to 1 st coupling above prod overshot. Cut 3-1/2" tbg just below coupling w/outside cutter @ 8,516'. POOH. LD fish (stub, 13 jts, x-nipple & cut off of 3-1/2" tbg) 431.11'. LD 15 jts of 5-3/4" wash pipe. MU BHA: (5-3/4" overshot dressed w/3-1/2" grapple 1.90') (Ext 3.59') (5- 3/4" x 2-1/4" top sub 1.01') (4-3/4" x 2-1/4" bumper sub 8.99') (4-3/4" x 2-1/4" oil jar 12.28') (12 DC's 370.18') (4-3/4" x 2-1/4" ACC jar 11.63'). RIH to top of fish @ 8,516'. Worked over fish @ 8,516'. Jarred & pulled on fish (hard to tell which overshot came loose). POOH. No fish. Redressed overshot (w/pack off). RIH. Worked over fish @ 8,516'. Appeared overshot not getting a good bite. POOH. Total pipe rec fr well: 8,486.28'. DWC: $30,446 CWC: $337,154 DMC: $1,642 CMC: $32,264 , 5/11/02 Fin TOH. LD partial fish consisting of 3-1/2" tbg stub & overshot used in completion. Length of fish 38.70'. Made up BHA consisting of 5-3/4" x 4-3/4" WO shoe (2.99'), 1 jt of 5-3/4" was pipe (32.15'), WO basket (286'), bumper sub (8.99'), oil jars (12.28'), 12 DC's (370.18'), ACC jars (11.63'). RIH to top of fish @ 8,552'. Washed over fish fr 8,552'-8,565' (apears to be milling on junk). Pmpd Hi-Vis sweep. Circ btms up. POOH. LD wash pipe & shoe (shoe well used up fr junk). Made up BHA consisting of 5-3/4" OS dressed w/3-1/2" grapple (1.90'),.ext (3.59'), top sub (1.01'), bumper sub (8.99'), oil jar (12.28'), 12 DC's (370.18'), ACC jars (11.63'). Repaired top drive (link tilt stud). RIH. Worked over fish w/OS @ 8,552'. Le jars hit @ 40K over string wt. Pulled 80K over string wt. OS or fish came free. POOH. LD partial fish consisting of 3-1/2" tbg stub, sliding sleeve & Guiberson pkr #2. Length of fish 24.60'. Holes in tbg just above sliding sleeve. Made up washover BHA consisting of WO shoe (2.68'), cutter (3.54'), 9 its of 5,3/4" WP (289.44'), bumper sub (8.99'), 12 DC's (370.18'). Total pipe recovered fr well 8,549.58'. http://dor/rept_mr.asp 6/18/2002 XTO Energy - Midland District Month!~. eport ~--.. Page 3 of 8 DWC: $37,095 CWC: $374,249 DMC: $1,577 CMC: $33,841 5/12/02 RIH w/9 jts of wash pipe to top of fish @ 8,571'. Worked over fish. Washed fr 8,571'-8,813'. Pmpd sweep. Circ btms up. Pulled up to next cplg, attempted to cut tbg. POOH, no fish. Stood back DC's & wash pipe. Re-dressed cutters. Serviced rig & top drive. RIH w/wash pipe & DC's (same BHA). RIH w/drill pipe. Slipped & cut drlg line. Washed over top of fish @ 8,571'. Washing dn over 3-1/2" tbg. DWC: $25,314 CWC: $399,563 DMC: $3,116 CMC: $36,957 5/13/02 Fin washing over 3-1/2" tbg fish fr 8,571'-8,813'. Circ btms up. Pulled up to next collar, cut tbg 2' below collar @ 8,785'. POOH. LD fish, rec 7 jts of 3-1/2" tbg & cut off. Total length of fish 216.13'. Made up fishing BHA consisting of 5-3/4" OS dressed w/3-1/2" grapples (1.90'), ext (3.59'), top sub (1.01'), bumper sub (8.99'), oil jars (12.28'), 12 DC' s (370.18'), ACC jars (11.63'). TIH. Worked over fish @ 8,785'. Fish came loose w/one lick of the jars @ 80K over. POOH. LD fish, rec 28' stub, GLM, 2' pup, 4' parted piece. Length of fish 38.80'. Made up wash over shoe (2.68'), 2 jts of 5-3/4" wash pipe (64.35'), WO bushing (2.89'), 4-3/4" bumper sub (8.99'), 4-3/4" oil jars (12.28'), 10 - 4-3/4" DC's (308.69'). RIH, tagged fill @ 8,816' (11' above top of fish). Washed fr 8,816'-8,857' (top of fish @ 8,827'). Pmpd sweep & dry job. Tot; pipe recovered fr well 8,804.69'. DWC: $92,854 CWC: $492,417 DMC: $1,156 CMC: $38,113 5/14/02 TOH w/wash pipe. Stood back DC' s. LD wash pipe assy. Pulled wear ring & set test plug. Press tstd plug, failed to hold press. Ran another plug. Press tstd BOP's to 250-5,000 psig, tstd okay. Witnessing of test was waived by Lou Grimaldi of AOGCC. Made up BHA consisting of 6" shoe (2.76'), 2 - 5-7/8" x 3-1/4" cages rolling dog (3.08'), ext (6.27'), WO basket (2.89'), 4-3/4" bumper sub (8.99'), 4-3/4" oil jars (12.28'), 10 - 4-3/4" DC's (308.69'). TIH. Circ over fish @ 8,827'. Washed to 8,838'. Circ hole. Mixed & pmpd dry job. TOH. LD fish consisting of a piece of 3-1/2" tbg (12.98'). Re-dressed rolling dog. TIH w/same BHA. Tagged top of fish @ 8,839'. Washed to 8,852'. Pulled loose w/20K overpull. Circ & pmpd dry job. Std TOH. Total pipe recovered: 8,817.67'. DWC: $30,179 CWC: $522,596 DMC: $1,681 CMC: $39,794 , 5/15/02 Fin TOH. LD fish. Rec stub of 3-1/2" tbg that had been jet cut. Length of fish 2.70'. Made up BHA consisting of 3-1/2" hollow mill guide (3.62'), 5-3/4" OS dressed w/3-1/2" grapples (1.55'), 3 top extensions (9.74'), top sub (1.01'), 4-3/4" bumper sub (8.99'), 4-3/4" oil jars (12.28'), 12 - 4-3/4" DC' s (371.02'), 4-3/4" ACC jars (11.63'). TIH. Worked over fish @ 8,852'. Worked dn to 8,857'. Circ hole. Mixed & pmpd dry job. TOH. LD fish. Rec 3-1/2" tbg fr jet cut to top of Otis sliding sleeve & 2-1/2" of collar on top of sliding sleeve. Length of fish 10.60'. Made up milling assy consisting of 6" x 1-1/2" flat btm mill (2.78'), 4-7/8" junk basket (3.65'), 4-3/4" bit sub (2.98'), 4-3/4" bumper sub (8.99'), 4-3/4" oil jars (12.28'), 12 - 4-3/4" DC's (371.02'). TIH. Tagged top of fish @ 8,852'. Milled to 8,853'. Slacked off weigl to 8,863' (w/o rotating). Set dn 15K wt @ 8,863'. Pulled up above fish 20'. Pmpd sweep & dry job. TOH w/6" mill. Made up BHA to fish fr sliding sleeve, 5-3/4" OS dressed w/4-1/4" grapple (1.90'), 3 extensions (9.74'), top sub (1.01'), 4-3/4" bumper sub (8.99'), 4-3/4" oil jars (12.28'), 12 -4-3/4" DC's (371.02') & 4- 3/4" ACC jars (11.63'). TIH. Worked cut lip guide to find top of fish @ 8,853'. Worked & jarred on fish, pulled free. Had press incr & some drag. Circ hole. Prep to TOH w/partial fish. Total pipe recovered: 8,830.97' DWC: $27,997 CWC: $550,593 DMC: $3,968 CMC: $43,762 , http://dor/rept_mr.asp 6/18/2002 XTO Energy - Midland District Monthl2~d~epog Page 4 of 8 5/16/02 Mixed & pmpd dry job. TOH. LD fish consisting of sliding sleeve, Guiberson pkr & 1/2 a jt of 3-1/2" jet cut tbg. Length of fish 25.10'. Made up wash over assy consisting of 5-3/4" x 3-1/2" hollow shoe (1.14'), 1 jt Wash pipe (32.19'), W.O. basket (2.89'), bumper sub (8.99'), oil jars (12.28') & 12 DC's (371.02'). TIH to 8,600'. Slipped & cut drlg line. Washed fr 8,793' to top of fish @ 8,877'. Dressed off jet cut flair. Washed over 3-1/2" tbg to 8,894' (top of GLM by DP measurement). Pmpd sweep. TOH. LD wash pipe & made up OS BHA consisting of 5-3/4" OS dressed w/3-1/2" grapples (1.90'), 3 extensions (9.74'), top sub (1.01'), 4- 3/4" bumper sub (8.99'), 4-3/4" oil jars (12.28'), 12 -4-3/4" DC's (371.02') & 4-3/4" ACC jar (11.63'). TIl Washed dn fr 8,800' to top of fish @ 8,877'. Swollowed fish to 8,888'. Worked fish free. Mixed & pmpd dry job. TOH. LD fish consisting of jet cut stub, GLM & 10' plugged tbg pup. Length of fish 22.64'. Made up wash over BHA consisting of 6"x 4-3/4" metal muncher shoe (2.06'), 5-3/4" wash pipe ext (6.27'), 1 jt 5-3/4" wash pipe (32.19'), W.O. bushing (2.89"), 4-3/4" bumper sub (8.99'), 4-3/4" oil jars (12.28') & 12 - 4-3/4" DC' s (371.02'). TIH. Total pipe recovered 8,878.71' DWC: $64,532 CWC: $615,125 DMC: $1,920 CMC: $45,682 5/17/02 TIH w/wash pipe assy. Washed over fish (GLM) w/6" x 4-3/4" shoe to 8,951' (top of pkr). Pmpd & circ sweep. POOH. LD wash pipe & shoe. Picked up OS w/4-3/4" grapple assy w/pmp out sub. TIH. Tagged top of fish @ 8,909' & caught same. Pulled 20K & fish came free. Dropped bar & sheared out circ sub. Pmpd dry job. POOH. Recovered 0.75' of GLM (rotten), pulled in two. LD fish & picked up OS & new 4- 3/4" grapple. TIH w/OS assy. Serviced rig, top dive & iron ruffneck. Trouble shooting electrical system. Lost 1 traction MTR. Contd TIH. Tagged top of fish @ 8,910' DPM, caught same. Grapple slipping off. Unable to maintain bite. Mixed & pmpd dry job. Prep to TOH. Recommended milling of GLM & tbg dn to good tbg for next fishing attempt. DWC: $30,102 CWC: $645,227 DMC: $1,572 CMC: $47,254 5/18/02 POOH & LD OS assy, no rec.' Tore out bad drawworks traction MTR. Picked up & made up milling assy. TIH. Reamed thru tight spot @ 8,864' DPM. Milled GLM & tbg fr 8,910' - 8,929'. Mill worn out. Pmpd sweep around. Installed new traction MTR for drawworks. DWC: $30,102 CWC: $675,329 DMC: $1,572 CMC: $48,826 5/19/02 Installed drawworks traction MTR. Pmpd dry job. POOH to 7,732' (past tight spot in csg). Wired up DC to new traction MTR for drawworks. Attempted to run w/generator #3, no good. Runs fine w/generator #1. Found burned wires in DC panel. Repaired same. Attempted to run. Ran good w/generators #3 & #5. Now generator #1, no good. Found fire in DC panel. DWC: $24,810 CWC: $700,139 DMC: $1,572 CMC: $50,398 :. 5/20/02 Replaced burned wiring in DC panel. Cody Misheler came out & inspected panel. Jim Fritz will be out Tuesday am. Rig should be operational by then & he can fine tune us. Sent 1 DA crew to beach. DWC: $18,081 CWC: $718,220 DMC: $1,572 CMC: $51,970 5/21/02 Electricians replaced wiring in DC panel. Rig crew assisted & worked on crane. J. Fritz should be out this AM. Plan to hook up last plugs & bring on line w/J. Fritz fine tuning. Hope to be operational by mid- morning to fin TOH. DWC.' $18,081 CWC: $736,301 DMC: $1,572 CMC: $53,542 5/22/02 Trouble shot DC panel. Tstd twice, still trying to scorch panel. Cleaned panel & tightened. Finally got a good tst. All generators okay. Std TOH w/milling assy. LD junk mill & cleaned junk baskets. Had trouble pulling wear ring. Backed out lock downs on tbg head. Pulled wear ring. Worked on lock downs (bent 2 of the stripped threads on packing nut). Attempted to repair (no replacements). Attempted to set test plug in hanger. Replaced seal. Set test plug hanger. Press tstd BOP. DWC.' $16,846 CWC: $753,147 DMC: $0 CMC: $53,542 : http://dor/rept_mr.asp 6/18/2002 XTO Energy - Midland District MonthJ,x~ eport Page 5 of 8 5/23/02 Press tstd BOP to 250-5,000 psig, tstd okay. Picked up milling assy. TIH. Milled fish fr 8,929'-8,935'. Unable to mill deeper. Mixed & pmpd Hi-Vis sweep & dry job. TOH. LD mill, not much wear. Fish may be spinning. Picked up OS/grapple assy to catch tbg above x-over sleeve & pkr. RIH & tagged top of fish @ 8,935'. Worked over & caught fish. Swallowed 10'+, jarred loose. Mixed & pmpd dry job. Std POOH (slow & wet). At report time fish @ 3,600'. DWC: $28,918 CWC: $782,065 DMC: $630 CMC: $54,172 5/24/02 POOH slowly. Broke out fish. Rec 9.38' of tbg w/twisted junk inside. Serviced rig & fixed lk on iron ruffneck PWR unit. RIH w/OS & 4-1/4" grapple assy. Attempted to catch fish @ 8,944'. Unable to get by junk to catch fish. Mixed & pmpd dry job. POOH. LD OS assy. Picked up bum shoe assy. TIH. Milled over fish fr 8,944'-8,951' (top of pkr). Pmpd sweep & dry job. TOOH. LD bum shoe assy. Shoe was tumec in fr csg OD (indicating tight spot in csg). Emptied junk baskets (lg chunks of GLM & csg). Picked up OS w/4-1/4" grapple. RIH w/OS assy to catch x-over sleeve & pkr. DWC: $31,360 CWC: $813,425 DMC: $3,459 CMC: $57,631 5/25/02 TIH w/OS w/4-1/4" grapple assy. Tagged fish @ 8,944'. Worked over fish to 8,949'. Attempted to catch, no success. Pmpd pill. TOH. Some wear on btm grapple. Rec 8" x 5" piece of GLM (above grapple). TIH w/OS & new 4-1/4" grapple. Tagged fish @ 8,944'. Worked over top of fish, got bite, jarred loose. Pmpd pill & POOH. Rec 5.5' offish, 1' of tbg, X-O SS & 0.50' of pkr. Had 2.5" x 2.5" piece of junk inside & 8" x 1/4" wrap around of 7" csg. Pkr pulled into @ anchor latch. LD OS assy & picked up 6" x 4-3/4" bum over shoe. TIH. Burning over pkr fr 8,949'-8,951' DWC: $29,497 CWC: $842,922 DMC: $1,371 CMC.' $59,002 5/26/02 Burned over pkr to 8,951'. Circ sweep & pmpd dry job. TOH. LD shoe (worn out). Emptied junk baskets, contained lots of junk. Picked up new bum over shoe. TIH. Burned over pkr to 8,954'. Top of slips & top of rubbers milled, should mm loose. Unable to make more progress. Circ sweep & pmpd dry job. TOH. LD old shoe (1/2 worn). Picked up one more shoe to get pkr or give up. TIH w/bum over shoe. DWC: $29,778 CWC: $872,700 DMC: $1,820 CMC.' $60,822 5/27/02 TIH w/bum over shoe assy. Burned over pkr fr 8,954'-8,958'. Fell over pkr. Pmpd sweep & dry job. TOH. LD bum over shoe & cleaned junk baskets. Picked up OS w/4-5/8" grapple assy. TIH. Tagged pkr @ 8,902' (must have pulled up hole w/shoe assy). Caught pkr. Dropped bar for circ sub. Pmpd dry job & POOH. Rec pkr, x-nipple & 2' of 3-1/2" tbg (tbg twisted apart). Fill holding tbg tail as pkr turned. Total rec 9.65'. Have 9.00' of tbg & Q-nipple still in fill. LD fish. Picked up mill assy for clean out. TIH. Worked thru tight spot @ 8,864'. Contd TIH. Milled tbg tail junk fr 8,961'-8,970'. Cleaned out fill fr 8,970'-9,147'. DWC: $30,179 CWC: $902,879 DMC: $1,650 CMC: $62,472 5/28/02 Cleaned out fill, junk & perfs fr 9,147'-9,349'. Unable to clean out any deeper (mill worn out). Discussed w/Paul & decided to make one more mill run. Pmpd Hi-Vis sweep & dry job. POOH. LD worn out mill & emptied junk baskets (had 7" csg sliver wrapped around mill). RIH w/new clean out mill & washed fr 9,259'-9,349'. Milled & cleaned out junk & ragged perfs fr 9,349'-9,440'. Solid @ 9,440'. Milling went slow until out of perfs. Circ Hi-Vis sweep & pmpd dry job. POOH. LD mill/clean out assy & picked up 7" RBP & retrievable pkr. TIH w/RBP/pkr assy. DWC: $30,828 CWC: $933,707 DMC: $1,580 CMC: $64,052 http://dor/rept_mr, asp 6/18/2002 X.TO Energy - Midland District Month~l.w~Report Page 6 of 8 5/29/02 Fin RIH w/Baker pkr assy (retrievable pkr & RBP). Set RBp @ 8,000'. Pulled up 30' & tstd RBP. Pulled up 90' & tstd csg (above RBP to 2,000 psig for 30", held solid), good tst. Pmpd pill. Retrieved RBP. POOH. LD pkr assy & picked up 3-1/2" muleshoe. Serviced rig & top drive. RIH w/3-1/2" muleshoe on 3- 1/2" DP, open ended to 9,420'. RU Dowell to pmp acid & held pre-job safety meeting. Pickled DP two times w/500 gals 10% HCL as per program & rev circ w/fig to pits & vented tank (w/250# SA added). Pmpd 1,220 gals 10% HCL & spotted over perf interval as per program. Let acid soak for 30" & rev out w/fig to pits & vented tnk. RD hard lines. Attempted to POOH (sticky). Circ & worked free w/50K over. Circ & pmpd sweep. Btms up revealed thick carbonate fr mud, probably stripped out by acid. DWC: $89,816 CWC: $1,023,523 DMC: $361 CMC: $64,413 5/30/02 Pmpd Hi-Vis sweep & dry job. POOH. Cleaned up rig floor. RU & chgd out top drive saver sub. Made up RBP, RIH & set @ 495'. Chgd out & repaired lock down screws on WH w/CIW WH hand. Pulled RBP, LD & stood back DC' s. Pulled wear ring. Made up tst assy. Tstd BOP fr 250-5,000 psig& LD tst assy. Made up btm prod pkr assy. RIH w/pkr assy on 3-1/2" DP (slowly). DWC: $38,054 CWC: $1,061,577 DMC: $361 CMC: $64,774 5/31/02 RIH w/Baker DB pkr & tail pipe on 3-1/2" DP. Dropped setting ball & set pkr @ 8,623'. Tops as follows: Baker Model 84-32 DB pkr @ 8,623', Baker 80-32 seal bore ext @ 8,627.17', 80-32 box by 2-7/8" RTS6 pin (chrome) @ 8,631.28', 2-7/8" RTS6 10' pup @ 8,631.83', RN nipple 2.18', profile @ 8,641.60', 2-7/8" RTS6 6' pup @ 8,642.88', Baker W-leg @ 8,648.65', Btm of W-leg @ 8,649.42'. RU to LD 3-1/2" DP. POOH, LD 3-1/2" DP. RIH w/4-3/4" DC's & 3-1/2" DP out of derrick. LD same. RU tbg tongs & jam equipment. Held PJSM. Std RIH w/2-7/8", RTS6, 7.9#, L-80 tbg (5,100' of tbg in hole @ rpt time). DWC: $30,739 CWC: $1,092,316 DMC: $0 CMC: $64,774 6/1/02 RIH w/2-7/8", RTS6, 7.9#, L-80 tbg. Stung into Baker SBR w/seal assy. Spaced out & landed tbg hanger. Had 280 jts of tbg on location. Ran 272 jts in hole (8 left on rack). RU to pickle tbg. Held pre-job safety meeting. DS pmpd 5 bbls FIW. Press tstd lines to 3,000 psig, tstd okay. Pmpd 12 bbls of 10% HC1, followed w/5 bbls FIW. Displaced w/rig pmp to 500' above seal assy. Reversed out to surf tnk w/rig pmp. DS pmpd 11 bbls of 10% HC1, followed by 5 bbls of FIW. Displaced w/rig pmp to 500' above seal assy. Reversed out to surf tnk W/fig pmp. Reverse circ tbg. Displacing annulus w/pkr fluid containing 10 gals NALCO ECl 124A + 4 gals NALCO EC1348 biocide per 100 bbls of FIW. Lwrd seal assy into SBR & landed tbg hanger w/tbg measurments as follows: W-leg @ 8,641.93', 80-32 bonded seals @ 8,635.52', locator @ 8,634.45', 2-7/8" RTS6 tbg pmp @ 8,624.31', 19 jts of 2-7/8" RTS6, 7.9#, L-80 tbg, R-nipple (ID 2.188") @ 8,024.21', 10' - 2-7/8" RTS6 tbg pup @ 8,014.21', 4-1/2" LTC by 2-7/8" RTS6 XO @ 8,013.38', 4-1/2" LTC mill out ext @ 8,008.50', SB3 pkr 9-chrome @ 8,004.23', 80-23 E-anchor @ 8,001.88', 2-7/8", EUE, 8rd pin by 2-7/8" RTS6 box XO @ 8,000.96', 2-7/8" RTS6 10' tbg pup @ 7,990.97', R-nipple (ID 2.188") @ 7,990.05', 244 jts 2-7/8" RTS6, 7.9#, L-80 tbg, R-nipple @ 335.16', 8 jts 2-7/8" RTS6, 7.9#, L-80 tbg, 4 tbg pups @ 68.88', 1 jt 2-7/8" RTS6, 7.9#, L-80 tbg, 2' tbg pup, Cameron tbg hanger w/3-1/2" EUE, 8rd threads in top @ 34.70' KB. Dropped prong DH & RU to set pkr. Press up on tbg to 4,000 psig, held for 15". Press up annulus to 2,000 psig, held for 30", good tst. RU wireline. Pulled prong & seat. Set PR plug in R-nipple @ 336' WLM. RD wireline. Set BPV. Std ND BOPS. DWC: $102,582 CWC: $1,194,898 DMC: $350 CMC: $65,124 6/2/02 Fin ND BOPS. NU production tree, press tstd to 5,000 psig, tstd okay. RU WL. RIH to pull plug in R- nipple @ 336' WLM. RD WL. Cleaned pits. Pmpd out 250 bbl tst tnk & injected fluid. Get ready for boat. Ready loads for boat & back loaded boat. Rig released @ 0600 hrs 6/2/02. Prep to move rig fr Leg gl to Leg #2. DWC: $108,007 CWC: $1,302,905 DMC: $0 CMC: $65,124 http://dor/rept_mr.asp 6/18/2002 XT0 Energy - Midland District MonthfLv-4Report ,---'-, Page 7 of 8 6/3/02 Started injecting FIW. Well pressured up to 3,500 psi after 20 bbls pumped. SD injection. Well bled down to 2,100 psi. SI well overnight to discuss situation. Appears that the perfs are plugged from the 11 ppg CaCO3 mud used during the workover. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 6/4/02 SIP @ 2,400 psi. Opened well to production, to backflow & attempt to cleanup perfs. Well is flowing back steady. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 6/5/02 Well is flowing back at very low rate. SI well @ 12:00 pm. Press built to 750 psi in 12-1/2 hrs. Opened well @ 12:30 am and bled down in 3 minutes. Put on injection @ 50 GPM for 15 minutes w/press increasing to 3,500 psi. Inj rate gradually decreasing to 25 GPM @ 3,500 psi. Will start to surge well back & forth by pressuring up to 3,500 psi w/sporadic bleed-downs. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 6/6/02 Pressured up well to 3,500 psi. Surged well about a dozen times w/quick bleed downs. Opened well over board to back flow after all pressure was released. Well was back-flowing much stronger then prior to last surge. Stream of water flowing vs. droplets. Put well back on injection @ 10:30 am @ 35 GPM (1,200 BWPD) w/press increasing rapidily. Injection rate dropped to 20 GPM (685 BWPD) after 15 minutes @ 3,500 psi. Rate was down to 15 gpm (514 BWPD) after 5 more minutes before losing all electricity on platform due to short on Main A/C Turbine. Left well SI while waterflood plant SD. Started back-flowing the well after being SI for 4 hours. Seem to be making progress by surging well due to back-flow stream getting a little stronger each time. Will check injectivity today & see if rate can be sustained. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 6/7/02 Contd to back, flow well. Returns started making more mud than previous "clean" water/Switched from going over board w/water to the slop tank. Flow is slowly getting stronger as more mud is coming back. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 6/8/02 Contd to back flow well. Fluid contains solids and decided to continue to back flow the well over the weekend to get wellbore as clean as possible before turning back to injection. Estimated rate was 80 BPD w/_+100 psi WHP. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 6/9/02 Contd to back flow well w/rate +170 BPD. Fluid is black w/some solids. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 6/10/02 Contd to back flow well. Solids in water are almost negligible. Will put well on injection today. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 6/11/02 Put well on injection at 5:00 am. Taking FIW @ + 500 BPD @ 3,500 psi best estimate until flow meter is calibrated. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 6/12/02 Injecting FIW @ 410 BPD @ 3,500 psi best estimate until flow meter is calibrated. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 6/13/02 Injecting FIW @ 370 BPD in 23-1/2 hrs @ 3,500 psi best estimate until flow meter is calibrated. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 http://dor/rept_mr, asp 6/18/2002 XTQ Energy - Midland District MonthNqReport Page 8 of 8 6/14/02 Injecting FIW @ 430 BPD @ 3,500 psi best estimate until flow meter is calibrated. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 6/15/02 Injecting F1W @ 484 BPD @ 3,500 psi. Good test W/Panametric meter now in service. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 6/16/02 Injecting FIW @ 619 BPD @ 3,500 psi. Panametric meter reading. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 6/17/02 Injecting FIW @ 634 BPD @ 3,500 psi. Panametric meter reading. Final report to Repair Tbg and/or Pkr Lk & RWTI. DWC: $0 CWC: $1,302,905 DMC: $0 CMC: $65,124 http://dor/rept_mr.asp 6/18/2002 ~ERGY XTO Energy Inc. 3000 North Garfield Suite 175 Midland, Texas 79705 915-682-8873 915-687-0862 (Fax) June 19,2002 Alaska Oil and Gas Conservation Commission Attn: Cammy Taylor 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Subject: RECEIVED JU ,l 2 1 2002 Alaska Oil & Gas Cons, Gontrm~a~o~' ancham0~ Submission of Form 10404 for the C34-23 Workover in the Middle Ground Shoal Field, Platform C. Dear Ms. Taylor, Please find attached the Report Form 10404, the Daily Workover Report, and the new current wellbore schematic for the C34-23 injector well. This well had been approved for the repair of the pressure communication on the tbg annulus. The old completion was pulled and replaced with 2 new permanent packers and new injection tbg. The well is back on injection with zero pressure on the tbg annulus. Please call me if you have any questions at (915) 620-6743. Sincerely, Paul L. Figel Sr. Production Engineer RECEIVED JUN 1 ZOOZ Cc: Doug Schultze Doug Marshall Tim Smith List of Attachments: 1. Form 10404 2. Current Wellbore Diagram 3. Daily Workover Reports STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test E-Mail to; Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: XTO ENERGY FIELD I UNIT I PAD: MIDDLE GROUND SHOAL PLATFORM C DATE: June 1, 2002 PYD: 67-51I 7, 999 7" lel1#:034.23 I S P ISALT WA TER ! a, oo4 l L.80 J 7.9# 700 2-7/812000 700 I700 , , 2,0001700 700I 2,000 2,000 IPl COMMENTS: Well #: I COMMENTS: PTD: ....... Well #:~ COMMENTS: I ! !1 PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: I I I I I I 11 TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL PAD. TRACER' SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 8.5 0.44 WELL TEST: Initial 4 - Year Workover X Other Distribution: orig- Well File OPERATOR REP SIGNATURE: c - operator c- Database c - Trip~erevised by L.G. 8~6~00 c - Inspector % Reese , AOGCC REP SIGNATURE: MIT MGS 34-23 6-1-022.xls 6/4/02 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend Operation shutdown Re-enter suspended well After casing Repair well X Plugging Time extension Stimulate Change approved program . Pull tubing Variance Perforate Other 2. Name of Operator 3. Address 3000 N. C-.at-l~ield, b'~e 175, Miclla~l, TX 79705 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface Platform,~_.~_"C" ,' Leg .1, .Conductor 535.88'N & 1597.22'W £rcat SE ,,~,.,,~,. o£ Sec. 23, T :R.1.3~, At top of prOductive interval V' 624.6'N & 1832'W frcm SE Oormer of Sec. 23, T8N, R13W, ~M At effective depth At total depth 669.6'N & 1907'W frcat SE ~ of Eec. 23, TSN, :R1..~'7, ~I 6. Datum elevation (DF or KB) :!_05' :K~ · 7. Unit or Property name 8. Well number C34 -23 9. Permit nu.m.b~ 10. APl number 50- 50-733-20041-00 11. Field/Pool YJ~i/"E", "F" & "C," Pools 12. Present well condition summary Total depth: measured true vertical 9642 ,feet 9633v' feet Plugs (measured) feet Effective depth: measured true vertical 9440 feet 9432 feet Junk (measured) Casing Length Structural Conductor Surface 2007 · Intermediate Production 954,5' Liner Perforation depth: Size 10-3/4", 40.5#, J-55 7", 26-29#, N-80 measured 8097-9419' true vertical 8092'-9412' (12 ~ntervals) Tubing (size. grade, and measured depth) Cemen~d 1850 sx 1100 mx Measured depth True vertical depth 2007 ' 9545' 2007' 9536' RECEIVED APR 1 9 2002 Alaska 0il & Gas Cons. Commission Anchorage 3-1/2",9.3~f, LS0 fYi:x:1 ]K,.'E 8rc1 0-8549'; 3-1/2",9.3#,N-80 & J-55 :IK./E 8rd. @ 8552'-8973' Packers and SSSV (type and measured depth) Guibe~son ~H-1 Packers @ 8568', 8860', 8954', Baker "SC-l" Packer @ 7999' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation ~ 6, 2002 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Servic, e X Suspended __ 17. I hereby ~ that the fore, ge, ing is true and correct to the best of my knowledge. Signed I'J~'"~ ~ ~,~ Title Sr. Pro~,~~n Emgiaeer FOR COMMISSION USE ONLY Date 4/18/02 Conditions of approval: Notify Commissio.n/so representative may witness ~"OOO~, t;~::>~-~'~-~t-~.~ IAppr°va' No. ~'~4::3,.~ -/.-~"> Plug integrity BOP Test "/,, Location clearance Mechanical Integrity Test ,')4~. Subsequent form required 10- t.~l;~ % . Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN TRIPLICATE XTO Energy Inc. MGS C34-23 COOK INLET, ALASKA WELL DATA: SURFACE CASING: LONGSTRING: PRESENT TUBING: PRESENT PACKERS: SMALLEST ID: DRILL PIPE: PROPOSED PKR's: PROPOSED TBG: PERFORATIONS: BHST: BHSP: PRESENT STATUS: OBJECTIVE: 10 SA" 40.5# J55. Set @ 2,007'. Cmt w/1,850 sx (2 Top Jobs). 7" N80. Set @ 9,545'. Cmt w/1,100 sx. TOC + 6,860' by CBL. Surface- 124': 29# 124 - 7,453': 26# 7,453 - 9,545': 29# 3 ½" 9.3# L80 Mod EUE 8R @ 8,549'. Set on 9-91. 3 ½" 9.3# N80 & J55 EUE 8R @ 8,552 - 8,973'. Set on 10-70. Baker Retrievable Pkr SC-1L @ 7,999'. Set on 9-91. Guiberson RH1 Pkr @ 8,568'. Set on 10-70. Guiberson RH1 Pkr @ 8,860'. Set on 10-70. Guiberson RH1 Pkr @ 8,954'. Set on 10-70. 2.75" ID in 5 ea X nipples & 3 ea Sliding Sleeves (See Schematic 4-15-02) (Q Nipple @ 8,973' ID = 2.635" is below Coil work) 3 ½" 15.5# S135 7" Baker SB-3 9Cr @ 7,983' 7" Baker DB L80 @ 8,623' 2 7/8" 7.9# RTS-6 L80 @ 8,650' GN-GO: 8,097 - 8,099' & 8,106 - 8,114' (Will be straddled by Packers) GR-GS: 8,407 - 8,439' (Will be straddled by Packers) HC-HD: 8,698 - 8,728' HE-HF: 8,799 - 8,844' HI-HK: 8,908 - 8,932' & 8,939 - 8,949' HK-HN: 8,966 - 9,088' HN-HR: 9,103 - 9,164 & 9,172 - 9,250' HR-HZ: 9,268 - 9,278' & 9,294 - 9,419' 165 Deg F +/- 5,500 psi Injecting @ 1,552 BPD @ 3,100 psi WHP, 3,050 psi Tbg annulus, 210 psi Surf Cs# press as of 4-15-02. Repair communication on injection well. Pull the current 4 packers & run a new injection string setting straddle packers over the GN - GS zones that will not be flooded. Final Procedure 4-18-02 XTO Energy Inc. MGS C34-23 Cook Inlet, Alaska NOTE: Derrick will be over the well. In Dec 1999, Slickline was unable to get below 1,163' w/a 2.60" gauge ring due to scale, but a 2.50" gauge ring made it to bottom. Will 1st attempt to make cuts w/APRS WL if slick line tools will make it to bottom. If not, will utilize Coil tbg to clean out the scale from the 31/z" tbg and then use WL jet cutter to make cuts b/w the packers. The well is practically vertical & WL tools should make it to bottom. After the tbg is cut, the rig wffi proceed w/the tbg & packer fishing operations. No KCL will be required for this completion. Regular FIW will suffice being an injector well. PROCEDURE: SD injection 2 weeks prior to workover. Need to determine if WL will get to bottom to make tbg cuts or if Coil tbg will be reqd to clean out the tbg. If possible, before the derrick moves over the wellhead, RU SL & press test lubricator to 3,000 psi. RI/-I w/2.50" gauge ring to 8,960'. POH. RIH w/2.60" to 8,960'. If successful, utilize APRS WL to cut the tbg. If SL can not get down hole, proceed with Coil TBG to clean out scale. APRS Job Procedure: a. RU APRS E-Line Unit. Press test lubricator to 3,000 psi. RIH w/2.5" jet cutter and make cut @ 8,900' (50' above PKR #1). POH. b. R]I-I w/jet cutter to make 2n~ cut @ 8,810' (50' above PKR #2). POH. c. RIH w/jet cutter to make 3r~ cut @ 7,950' (50' above PKR #3). PoH. RD APRS. Cont procedure @ Step #6. Alternate Coil Tubing Procedure: MIRU Derrick from C32-23LW. following: Coordinate Coil tbg arrival to be rigged up after derrick is over well. MIRU the 1 ~A" Coil Tbg Unit: Install press gauges on CT, CT annulus and 3 V2" tbg annulus. 2 ea 5,000 psi Triplex Pumps (1 pump for Coil Tbg pumping, 1 pump for fluid transfer to disposal well) N2 Bottles to blow Coil Tbg Reel dry after job Baker 3 V2" Turbo Scale Mill Baker 2 1/8" Navidrill Motor 250 bbl, 120psi production tank for acid/solids returns (already on deck frOm C32-23LW) )~ Choke Manifold to contain a sample catcher. (Supplied by Coil Tbg Co.) )~ Send "clean" returns to Production Facilities. )~ Send live acid and or fluids containing solids to Production Tank - Neutralize acid w/Soda Ash before pumping to Disposal Well (C44-14). Mud Pits will be used for ~mixing the gel sweeps Materials Required: · Friction Reducer for FIW (Supplied by Coil Tbg Co.) · 200 bbl Xanthan Gel Pill (2# / bbl Flo-Visc + 5 gal / 100 bbl Greencide) (Supplied MI) )~ Use FIW as base fluid Final Procedure 4-18-02 XTO Energy Inc. MGS C34-23 Cook Inlet, Alaska . RU Coil Tbg BOP's and test lines to 6,000 psi. Max press is 5,000 psi. CTU operator to ensure all tools are to be calipered before RIH. MU Baker 2 7/8" Turbo Scale Mill & 2 I/8" Navidrill Motor. Smallest ID is 2.75" @ X nipples (5 ea) & sliding sleeves (3 ea). See attached Current Schematic dated 4-15-02. 2. Hold safety meeting with all service & production personnel about the procedure, corrosive chemicals, and possible H2S exposure. . Open CT annulus. RIH w/Coil Tbg while pumping slick FIW @ 1.5 BPM. Clean out scale in the tbg to 8,960' (top of last X nipple) while circulating returns to the 250 bbl production tank. Pump 10 bbl Visco Sweeps when necessary to keep the hole clean. POH after tbg is clean. RD Coil Tbg. Coil Tbg to stand-by to make sure APRS can get to bottom. 4. RU APRS E-Line Unit. Pressure test lubricator to 3,000 psi. RIH with 2 5/8" jet cutter and make cut @ 8,900' (50' above PKR gl). POH. 5. RIH w/jet cutter to make 2nd cut @ 8,810' (50' above PKR #2). POH. RD APRS & stand-by while BOP's are rigged up. Release Coil tbg. 6. RU mud pump to WH. Circ well w/FIW to clean out & kill well. 7. Set BPV. ND tree and NU BOP's. PO BPV & set DBL check valve. Test BOP's to 250 & 5,000 psi. Rig up to attempt to pull the Baker SC1 retrievable Pkr @ 7,999'. The Tri-State Overshot Pack-off below the SC-IL packer should pull w/the packer. If the Baker Pkr will not come free, maintain tension on tbg, RIH with APRS string shot & shoot the tbg above the Pkr. POH w/APRS. POH w/tbg & Packer and Overshot. Proceed w/Step #12. 9. If Step #8 fails, RIH w/jet cutter to make 3ra cut @ 7,950' (50' above PKR #3). POH. APRS to stand-by until last packer is free. 10. POH 3 ½" cut tbg from 7,950' & LD. 11. RU Baker fishing equipment. RIH w/overshot & jars on 3 ½" DP. Fish out Packer #4, Baker SC-iL, @ 7,999' w/the Tri-State Overshot Pack-off below the SC-iL. POH. 12. RIH & fish out Packer #3, Guiberson RH1, @ 8,568'. Tbg stub is @ 8,552'. POH. 13. RIH & fish out Packer #2, Guiberson RH1, @ 8,860'. POH. 14. RIH & fish out Packer #1, Guiberson RH1, @ 8,954'. POH. LD fishing tools. 15. RIH with a bit & scraper for 7" 29# to PBTD @ 9,440'. Reverse out hole clean w/20 bbl Visco Gel Sweep (2# / bbl Flo-Vis + Greencide) followed with FIW. 16. RU Acid Company & 250 bbl surface production tank for acid returns. RU manifold w/sample catcher to send liquid to both the production facilities & the prod tank. Press test lines to 3,000 psi. 17. Pickle the 3 V2" DP w/500 gal 10% HCL Pickle Acid @ 2-3 BPM. Under displace the acid by 500' from the end of DP with FIW on all Pickle ,lobs. Reverse out acid to surface tank. Repeat Pickle Job w/500 gal 10% HCL. Neutralize acid w/250 lbs soda ash before sending to the disposal well C44-14. Final Procedure 4-18-02 XTO Energy Inc. MGS C34-23 Cook Inlet, Alaska 18. Spot 1,300 gal (31 bbl) 10% Iron Control HCL Acid across HC-HZ: 9,420 - 8,650'. Displace w/FIW. Let acid soak for 30 minutes. Circ out acid to the production tank w/FIW. POH & LD bit & scraper. Acid Equipment to Stand-by for pickle job on injection string. 19. PU Baker 7" RBP & Retrievable Packer. RIH and set RBP @ 8,000'. PU 1 stand and break circ. Set Packer. Press test annulus to 2,000 psi. If casing passes press test, POH w/pkr & RBP. Contingency Plan for Casing Leak: Locate any casing leaks & verify if possible, with a minimum of 3 different injection rates (1, 2, 3 BPM). Note the injection pressure at each rate & notify the Midland office. Will determine possible squeeze job at that time. 20. RU Weatherford JAM monitor system. RII-I and set 1st Baker 7" "DB" L80 Packer on 3 ¥2" DP @ 8,623' as follows: LOWER PACKER: Item Length Top Btm 7" Baker DB Pkr (84-32) L80 3 8,623 8,626 Baker 5' Sealbore extension 9Ct 5 8,626 8,631 X-Over Acme Box to 2 7/8" RTS-6 Pin I 8,631 8,632 10' Pup Jt, 2 7/8" 7.9# RTS-6 L80 10 8,632 8,642 2 7/8" RN Nipple (2.01" ID) 9Ct I 8,642 8,643 6' Pup Jt, 2 7/8" 7.9# RTS-6 9Cr 6 8,643 8,649 WL re-entry guide w/pumpout plug @ 3,000 to 3,200 psi 1 8,649 8,650 21. POOH w/DP. 22. RII-I with 2na Baker 7 .... SB-3" Chrome Packer on 3 V2" DP and set @ as follows: UPPER PACKER: Item Length Top Btm 2 7/8" 7.9# L80 RTS-6 Tbg 300 0 300 2 7/8" R Nipple (2.188" ID) RTS-6 9Ct 1 300 301 2 7/8" 7.9# L80 RTS-6 Tbg (+/- 240 Jts) 7,669 301 7,970 2 7/8" R Nipple (2.188" ID) RTS-6 9Ct 1 7,970 7,971 10' Pup Jt 2 7/8" 7.9# RTS-6 9Ct 10 7,971 7,981 X-Over RTS-6 Box to 2 7/8" 8R Pin 1 7,981 7,982 ~E Anchor (80-32) L80 1 7,982 7,983 7" Baker SB-3 Perm Pkr (84-32) 9Cr 3 7,983 7,986 6' Millout Ext (4 Y2" OD) LTC 12.6# 14Cr 6 7,986 7,992 ~X-Over 4 ~" LTC Box to 2 7/8" RTS-6 Pin I 7,992 7,993 !10' Pup Jt, 2 7/8" 7.9# RTS-6 L80 10 7,993 8,003 Prong 1 2 7/8" R Nipple (2.188" ID) RTS-6 9Ct 1 8,003 8,004 2 7/8" 7.9# L80 RTS-6 Tbg (19 its) 608 8,004 8,612 10' Pup dt, 2 7/8" 7.9# RTS-6 L80 10 8,612 8,622 Locator (5' bonded Seals) { I 8,622 8,623 Final Procedure 4-18-02 XTO Energy Inc. MGS C34-23 Cook Inlet, Alaska 23. Locate bottom packer @ _8,623 & space out. PU 1 stand & RO w/FIW minimum 50 bbl to obtain good returns. Sting into packer w/seal assembly. Attempt to reverse circ to ensure lower seals are in bottom packer with max 1,000 psi. Pull up 1 stand & prepare to pickle the tbg. 24. RU Acid Co. & press test lines to 3,000 psi. Est circ w/FIW. Pickle the tbg w/500 gal 10% HCL Pickle Acid @ 2-3 BPM. Under displace the acid by 500' from the end of tbg with FIW. Reverse out acid to surface tank. Repeat Pickle Job with 500 gal 10% HCL. NeUtralize acid w/250 lbs soda ash before sending to disposal well. RD Acid Co. 25. Prior to stinging into pkr, circ (+ 280 bbl) pkr fluid containing: 10 gal Nalco ECl 124A + 4 gal Nalco EC1348 Biocide per 100 bbI of FIW. Lower pkr assembly. Drop prong DH. Press up to + 4,000 psi to set top packer. 26. Press test annulus to 2~000 psi for 30 minutes. Notify AOGCC 48 hours prior to press test. Hang off 2 7/8" tbg in SS tbg Hangar. Set BPV. ND BOP's. NU WH and test WH to 5,000 psi. Pull out BPV. 27. RU slickline & POH prong. RD slickline. Press test TBG to 1,000 psi for 15 min. Monitor falloff. Continue to pressure up on tbg to 4,700 psi (expected reservoir press is 5,500 psi and hydrostatic of approximately 3,800 psi) to pump out plug. 28. Notify AOGCC 48 hrs prior to MIT and start of injection. Target injection rate is 1,000 BWPD @ 3,600 psi. Release Rig. Do NOT start injection until the corrosion and scale inhibitor chemicals are being injected. 29. Document all uses of the disposal well with volumes & fluids in the "Disposal Log Book" on board. Paul L. Figel Sr. Production Engineer Doug Schultze VP,' Operations Final Procedure 4-18-02 MGS C34-23 WIW Cook Inlet, Alaska Leg 1, Conductor 6 APl No.: 50-733-20041 Spud: 9-13-67 24' Conductor @ 370' Surf Csg: 10 3/4", 40.5 lb, J55. Set @ 2,007'. Cmt w/1,850 sx. TOC @ surface w/2 Top Jobs. TOC (CBL) @ +/-6860'. Present Completion PLF 4-15-O2 KB: 105' Water Depth: 73' MSL Tubing: -' 3 1/2" 9.3# L80 Mod EUE 8R @ 8,549' Set 9-91. 3 1/2" 9.3# N80 & J55 @ 8,552 - 8,973' Set 10-70. X Nipple @ 327' (2.75" ID) X Nipple @ 7,965' (2.75" ID) Baker "EBH-22" Tubing Locator @ 7,998' Baker "SC-1" Retrievable Pkr @ 7,999' Set 9-91 Baker Mill-Out Extension @ 8,004' X-Over 5" LTC Box x 3 1/2" Pin 16 Jts 3 1/2" 9.3# 8R Tbg X Nipple @ 8,516' (2.75" ID) I Jt 3 1/2" 9.3 # 8R Tbg Tri-State Overshot Pack-Off @ 8,549 w/UTEX Seals Otis XO Sliding Sleeve @ 8,564' (2.75" ID) Guiberson RH-l'Packer @ 8568' Set 10-70. Camco KBM Dummy Mandrel @ 8,819' Otis XO Sliding Sleeve @ 8,856' (2.75" ID) Guiberson RH-1 Packer @ 8860' Set 10-70. X Nipple @ 8,866' (2.75" ID) Camco KBM Dummy Mandrel @ 8,898' Camco KBM Dummy Mandrel @ 8,914' Otis XO Sliding Sleeve @ 8,951' (2.75" ID) Guiberson RH-1 Packer @ 8,954' Set 10-70. X Nipple @ 8,961' (2.75" ID) Otis Q Nipple @ 8,973' (2.635" ID) . EOT @ 8,973' Top of 3 1/2" tbg stub @ 8,552' Scale Obstruction @ 8,557' Prod Csg: 7" N80 set @ 9,545'. 'Surface - 124': 29# 124 - 7,453': 26# 7,453 - 9,545': 29# Cmt w/1100 sx. Bkr Retrievable SC1 Pkr @ 7999' Set 9-91 GN-GO: 8097'-8099' G N-GO: 8106'-8114' GR-GS: 8407'-8439' Guib RH1 pkr @ 8568' Set 10-70 HC-HD: 8698'-8728' HE-HF: 8799'-8844' Guib RH1 pkr @ 8860' Set 10-70 HI-HK: 8908'-8932' HI-HK: 8939'-8949' Guib RH1 pkr @ 8954' Set 10-70 Top of Fill @ 9,390' PBTD: 9,440' MD (9,432' TVD) TD: 9,642' MD (9,633' TVD) HK-HN: 8966'-9088' H N-H R: 9103'-9164' .HN-HR: 9172'-9250' HR-HZ: 9268'-9278' HR-HZ: 9294'-9419' ·':1'O MGS C34-23 WIW Cook Inlet, Alaska Leg 1, Conductor 6 APl No.: 50-733-20041 Spud: 9-13-67 24' Conductor @ 370' Surf Csg: 10 3/4", 40.5 lb, J55. Set @ 2,007'. Cmt w/1,850 sx. TOC @ surface w/2 Top Jobs. TOC (CBL) @ +/- 6860'. Proposed Completion PLF 4-16-02 KB: 105' Water Depth: 73' MSL Tubing: 2 7/8" 7.9# RTS-6 L80 @ 8,650' Set: 2 7/8" R Nipple (2.188" ID) 9Cr @ 300' 240 Jts 2 7/8" 7.9# L80 RTS-6 Tbg . 2 7/8" R Nipple (2.188" ID) 9Cr @ 7,970' 10' Pup Jt. 2 7/8" 7.9# RTS-6 9Cr X-Over RTS-6 Box to 2 7/8" 8R Pin "E" Anchor (80-32) L80 @ 7,982' 7" Baker SB-3 Pkr (84-32) 9Cr @ 7,983' 6' Millout Ext. LTC 12.6# 14Cr @ 7,986' X-Over 4.5" LTC Box to 2 7/8" RTS-6 Pin 10' Pup Jt. 2 7/8" 7.9# RTS-6 L80 2 7/8" R Nipple (2.188" ID) 9Cr @ 8,003' · 19 Jts 2 7/8" 7.9# L80 RTS-6 Tbg 10' Pup Jt. 2 7/8" 7.9# RTS-6 L80 @ 8,612' Locator 5' Bonded Seals (80-32) @ 8,622' 7" Baker DB Pkr (84-32) L80 @ 8,623' 5' Sealbore Ext 9 Cr @ 8,626' X-Over Acme Box to 2 7/8" RTS-6 Pin 10' Pup Jt. 2 7/8" 7.9# RTS-6 LB0 2 7/8" RN Nipple (2.01" ID) 9Cr @ 8,642' 6' Pup Jt. 2 7/8" 7.9# RTS-6 9Cr WL Re-entry Guide @ 8,650' GN-GO: 8097'-8099' G N-GO: 8106'-8114' GR-GS: 8407'-8439' Prod Csg: 7" N80 set @ 9,545'. Surface - 124': 29# 124 - 7,453': 26# 7,453 - 9,545': 29# Cmt w/1100 sx. HC-HD: 8698'-8728' HE-HF: 8799'-8844' hl-hk: 8908'-8932' HI-HK: 8939'-8949' PBTD: 9,440' MD (9,432' TVD) TD: 9,642' MD (9,633' TVD) HK-HN: 8966'-9088' HN-HR: 9103'-9164' HN-HR: 9172'-9250' HR-HZ: 9268'-9278' HR-HZ: 9294'-9419' Re: Cross Timbers MGS C34-23 Water Inj Well - -~D 67-051 Subject: Re: Cross Timbers MGS C34-23 Water Inj Well-- PTD 67-051 Date: Tue, 14 Dec 1999 14:42:02-0900 From: Blair Wondzell <blair_wondzell~admin. state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: cpope~xtookc.com CC: marshall~sarcomgs.com, Tom Maunder <tom_maunder~admin.state.ak.us> Mr. Charles Pope, Thanks for your E-mail report on MGS well C-34-23. You have verbal approval to continue injection and doing diagnostic work until such time as injection parameters indicate "out-of-zone" injection, or a combined tubing/tubing-casing annulus MIT demonstratres the casing still has integrity; at that time a 10-403 "Sundry Notice" to either shut the well in or for continued injection will be required. Sincerely, Blair Wondzell 12/14/99. cpope@xtookc.com wrote: > December 14, 1999 > Blair Wondzell > AOGCC > Dear Blair, > As we discussed today on the telephone, the MGS C34-23 WIW has developed pressure communication between the tubing and casing. This was first observed on Sunday, December 12, 1999. I had left you a message on Monday, December 13, 1999 to begin the notification process to you. > Injection rate and surface pressures have been monitored closely since identification of the communication to the annulus. There has been no increase in injection rate since the communication to the annulus. Cross Timbers will continue to monitor the injection rate and pressure on a daily basis. Injection will be shut down immediately if the injectivity increases significantly for unexplained reasons. We are currently examining our well records and will attempt to wire line set a plug in the tubing to test the tubing and casing integrity. We shall keep you informed of our progress. > > We request approval to continue injection operations on C34-23 until further action is taken. > > Sincerely, > Charles Pope > Production Engineer > Cross Timbers Operating Company > 405-319-3211 1 of 1 12/14/99 2:42 PM Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 December 16, 1991 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Gentlemen: SUBJECT: SUBSEQUENT REPORT FOR MIDDLE GROUND SHOAL WELL C34-23 Enclosed are duplicates of the Subsequent Report for the recently completed stimulation work of Middle Ground Shoal well C34-23. The operations were completed on October 12, 1991'. If you need additional reports or information, please contact Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, Manager Alaska Operations Western Division RGB/SBBM/dlw Enclosures SBBM~121691B.WP5 RECEIVED DEC 20 1991 Alaska Oil & Gas Cons, Commisslen Anchorage STATE OF ALASKA . REPORT OF' SUNDRY WELL OP/=RATIO 1. Operations pedormed: Operation shutdown __ Stimulate X Plugging__ Perforate __ Pull tubing X Alter casing Repair well X Other 5. lype ot Well: 6. Datum elevation (DF or KB) 2. Name of Operator Shell Western E&P Inc. Developmen~Y~ 105' KB feet 3. Address 601 W. 5th Avenue, Suite 810 F__xplorato~/ 7. Unit or Property name Anchorage, AK 99501 S~ratigraphic Middle Ground Shoal Servk:e -'~ 5"~t 8. Well Numoer 4. Location of well at surface Platform "C", Leg 1, Conductor 6. 535.88'N and 1597.22'W C34-23 from SE Comer of Sec. 23, T8N, R13W, SM 9. Permit number/approval number At top of productive interval 624.6'N an~l 1832'W from SE Corner of Sec. 23, T8N, R13W, 67-51/91-226 SM 10. APl number At effective depth 50-733.20041-00 669.6'N and 1907'W from SE Comer of Sec. 23, T8N, R13W, 11. Field/Pool At total depth SM MGS/"E", "F" & "G" Pools 12. Present well condition summery Total depth: measured 9642 feet Plugs (measured) true vertical 9633 feet Effective depth: measured 9440 feet Junk (measured) true vertical 9432 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Sudace Intermediate 200T 10-3/4", 40.5~, J'55 1850 sx 2007' 2007' Production 9545' T', 23-29,9, N-80 1100 ex 9545' 9~36' Liner Perforation depth: measured 8097' - 9419' true vertical 8092' - 9412' (12 Intervals) Tubing (size, grade, and measured depth) 3-1/2", 9.3~, L-80 EUE 8rd 0'-8549'RECEIVED 3-112", 9.3it, N-80& J-55 EUE 8rd @ 8552'-8973' Packers and SSSV (type and measured depth} Guiberaon RH-1 Packers ~]~ 8568', 8860', 8954' Baker "SC-1" Packer @ 7999' DEC 20 1991 13. Stimulation or cement squeeze summary Alaska 0ii & Gas Cons, Commissle~ Intervals treated (measured) 8698' - 9419' Anchorage Treatment description Including volumes used and final pressure CTU Aoid eoak, waeh, aClUeeZe. Total acid volume,101 bbls. Squeeze ISIP = 2500 psi. , 14. Reoresentative Daily Averaae Production or Inlection Data OiI-Bbl Gas-MGf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A SI 37 0 Subsequent to operation N/A N/A 1401 0 3500 , 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys mn Daily Report of Well Operations ~| Oilm Gas__ Suspended__ Service InJeotlon 17. I nereOy certify that the foregoing is true and correot to the Dost ol my Knowleage Form 10-404 Rev 0(J /15/88 SU BM IT IN DUPLIGATE Di%TLy REPORT WELL: C34-23 DAILY SUMMARY - (from 0600 hrs prior day to 0600 hrs today) 08/28/91 - SKID RIG OVER C34-23 AND RIG UP. - KILL WELL WITH 12.2'PPG CALCIUM CARBONATE MUD TAKING RETURNS TO PRODUCTION HEADER. FLUID RETURN SAMPLES DID NOT INDICATE ANY TUBING LEAKS. MADE ONE COMPLETE CIRCULATION. WELL DEAD. - RIG UP DIA-LOG, RUN IN HOLE WITH TUBING STRING SHOT AND SHOOT AT 8545' TO DISLODGE ANY SCALE INSIDE TUBING. RUN IN HOLE WITH DIA-LOG CHEMICAL TUBING CUTTER. MAKE CUT AT 8545'. INDICATIONS ARE, CUT WAS SUCCESSFUL. - PULL OUT OF TUBING WITH SPENT CUTTER AT REPORT TIME. 08/30/91 - FINISHED TIH W/6" MILL/SCRAPER T/8550' DRILL PIPE MEASUREMENT. VERY GENTLY TAGGED STUB. - CIRC/COND AT TOP OF TBG STUB. - POH, LAYED DOWN MILL/SCRAPER - MAKE UP AND TIH W/HOWCO RTTS T/8033'. - SET RTTS AT 8033'. PRESSURE TEST CSG T/2200 PSI F/30 MINS OK. - CDL 100'. - POH, LAYED DOWN RTTS. - MAKE UP STUB DRESSING MILL ASSMY. TIH. - DRESS OFF TBG STUB AT 8550'. - POH W/STUB DRESSING TOOLS AT REPORT TIME. - NO ACCIDENTS REPORTED. 08/31/91 - FINISHED POH W/TBG STUB DRESSING MILL. - MAKE UP TRI-STATE OVERSHOT PACK-OFFW/5.750" O.D. GUIDE, WITHOUT THE UTEX SEALS, PIH. TRY TO WORK OVER STUB AT 8550'. - RIG UP SLICKLINE. RIH W/1.90" TAPERED GAGE. TAGGED UP ON TBG STUB. POH RIH W/1.75" IMPRESSION BLOCK. POH. HAD GOOD IMPRESSION OF TBG EDGE. RIG DOWN SLICKLINE. - POHW/OVERSHOT. MARKS ON GUIDE ALSO SHOWED WAS NOT OVER TBG STUB. LAYED DOWN OVERSHOT. - MAKE UP HOWCO 5.750" IMPRESSION BLOCK ON DC'S/DP, TIH, SET 3K WEIGHT ON TBG STUB, POH. CLEAR IMPRESSION SHOWED TBG STUB LAYING HARD AGAINST SIDE OF CSG, AND WHERE THE OVERSHOT HAD RUN ON IT DURING EFFORTS TO GET OVER THE STUB LAST TRIP. RECEIVED DEC 20 199! Ala$~ Oil & Gas Cons. Commission Anclmrage D~ILY REPORT WELL: C34-23 08/31/91 - TIH W/STUB DRESSING TOOL TO RE-DRESS STUB AT RPT (CONT'D) TIME. - NO ACCIDENTS REPORTED. 09/01/91 - RE-DRESS TBG STUB 8550'· - POH, LAY DOWN DRESSING MILL. - MAKE UP HOLLOW MILL, 3·5" I.D., 10' WASH PIPE, BHA, TIH. - WASH OVER, CLEANING OFF SCALE FROM TBG O.D. F/8550' T/8562'. - CIRC HOLE CLEAN. RECOVERED 5 GAL BUCKET OF SCALE. - POH, LAY DOWN HOLLOW MILL ASSMY. - MAKEUP TRI-STATE PACK-OFF ASSMY, WITHOUT UTEX SEALS, TIH. - RIG UP SLICKLINE. RIH W/1.90" TAPERED DRIFT. TAGGED UP AT 8557' WLM. NO MARKS ON TOOL. RIH W/IMPRESSION BLOCK, POH. NO MARKS ON TOOL· RIH W/PUMP BAILER. WIRELINE UNIT STRIPPED SET SCREW ON DRIVE SHAFT. - REPAIR WIRELINE UNIT. - POHW/BAILER. HAD CUP FULL OF VERY FINE SCALE. RUN BAILER AGAIN AT RPT TIME. - NO ACCIDENTS REPORTED. 09/02/91 - POH W/BAILER. CUP OF SCALE RECOVERED. RIG DOWN SLICKLINE. CDL 100'· , - POH W/TRI-STATE OVERSHOT. INSTALL UTEX PACKING· TIH W/OVERSHOT ASSMY. - STAB OVER TBG STUB AT 8550' LOWERED SEALS 7' OVER. (8557') PRESSURED UP ON ANNULUS, W/TBG OPEN, T/1000 PSI. SEALS HELD· DRIP 1 7/16" BALL· PRESSURED UP T/2500 PSI, PULLED 25K ABOVE STRING WEIGHT T/SET SC-IL BAKER PACKER. PUMPED BALL INTO CATCHER AT 3500 PSI. ROTATE 15 TURNS TO RIGHT, RELEASING F/PACKER. PACKER TOP AT 7999' OTIS X NIPPLE AT 8516' ALL TBG IS 3 5" · · · , 9.3#, L-80, 8RD EUE, R-2. - POH W/RUNNING TOOL ASSMY. - PULLED WEAR BUSHING. MAKE UP BAKER EBH-22 SEAL ASSMY, 1 JOINT 3.5" TBG, OTIS X NIPPLE, RAN 244 JTS TBG, OTIS X NIPPLE, 9 JTS TBG. PREP T/REVERSE CIRC T/CLEAN OUT ANY PIPE DOPE/SCALE PRIOR T/RUNNING PXN PLUG/PRONG· Alaska 011 & Gas Cons. Commlsslen AncHorage DAILY REPORT WELL: C34-23 09/02/91 - NOTE: THE TOP 247 JTS OF TBG ARE AB MOD. THE (CONT'D) BOTTOM 24 JTS ARE NOT. ALL ELSE IS THE SAME. 3.5", 9.3#, L-80, 8RD EUE, R-2. - NO ACCIDENTS REPORTED. 09/03/91 - REVERSE CIRC 2 TBG VOL'S T/REMOVE ANY SCALE/DOPE PRIOR T/SETTING PLUG. - RIG UP SLICKLINE. SET PXN PLUG/PRONG IN "X" NIPPLE AT 8516'. RIG DN. - SPACE OUT TBG HANGER F/8000# SET DOWN WEIGHT ON LOCATOR AS HANGER LANDS. PICKUP, UNLATCH F/PACKER, UNSTING SEALS F/SEAL BORE. - REVERSE CIRC 25 BBL POLYMER SWEEP. DISPLACE MUD W/FIW UNTIL HOLE WAS CLEAN. (CAPTURED MUD IN PITS/STORAGE TANK) SPOTTED 212 BBLS FIW WITH .04% VISCO 3900 IN ANNULUS. - STING IN/LATCH SEALS, PICKUP CONFIRMED LATCHED, LAND HANGER W/8000# WT ON LOCATOR. UP WEIGHT WAS 94K/DOWN WEIGHT WAS 94K IN 8.5 PPG FLUID. PRESSURE TEST TBG T/3500 PSI, OK. TEST ANNULUS T/2200 PSI, OK. RECORD ON CHART, FAX'ED TO AOGCC PER REQUEST F/THEIRMR. BLAIR WONDZELL. TEST WAS- 30 MINS. ON ANNULUS. BLEED OFF PRESSURE. - INSTALLED BPV. NIPPLE DOWN BOPE. NIPPLE UP TREE. TEST HANGER/SEALS TO 5000 PSI OK. TEST TREE BODY T/5000 PSI, OK. - TBG/EQUIP DETAIL "AS RAN" TBG MEASUREMENTS: - TRI-STATE OVERSHOT W/UTEX SEALS; 8558' UP T/8549'. BTM T/TOP. - OTIS "X" NIPPLE AT 8516'. - TOP OF BAKER "SC-iL" PACKER AT 7999'. - OTIS "X" NIPPLE AT 7965'. - OTIS "X" NIPPLE AT 327'. - THERE IS A 2' THEN A 10' PUP BELOW TBG HANGER. 271 JTS TOTAL TBG RAN. - 8490.20' OF 3.5" 9.3# L-80 8RD EUE. BOTTOM 24 JTS ARE NOT AB MODIFIED. THE OTHER 247 ARE. - NO ACCIDENTS REPORTED. 09/04/91 - RIG UP SLICKLINE. PULL PRONG/PXN PLUG FROM "X" NIPPLE AT 8516'. - RIG DOWN SLICKLINE. - PREP FOR DE-MOB/STORAGE OF RIG/COMPONENTS. - THIS REPORT 7 HRS ONLY. 0500 HRS TO NOON. - NO ACCIDENTS REPORTED. RECEIVED D EO 0 1991 Alaska 011 & G~s Cons. CommlSSlen Anchorage D~ILY REPORT WELL: C34-23 10/11/91 - CONTINUE REPAIRING 3900 CRANE. - CONTRACT PERSONNEL CAME ON BOARD FOR RIG UP. - HELD GENERAL PLATFORM SAFETY MEETING, ORIENTATION, AND REVIEW OF SAFE WORK PLAN. - RIG UP EQUIPMENT. - SECURE OPERATION FOR NIGHT @ 2400 hfs, 10/10/91. 10/12/91 - HELD SAFETY & PROJECT MEETING WITH PRODUCTION & CONTRACT PERSONNEL @ 0600 hrs. ADDRESSED SAFE WORK PLAN & RESPONSE CONTINGENCIES. - RIG UP ON C34-23 WITH CTU INJECTOR HEAD ASMY. PRESSURE TEST ALL WELL CONTROL EQUIPMENT. PRESSURE TEST ALL SURFACE FLUID HANDLING PIPING, VESSELS. AND PUMPS. - OPEN WELLHEAD, RIH W/2.5" 3 LOBE MILL, 2.0625" PDM, DBLCV. - TAG BRIDGE @ 8,556' RKB. ENCOUNTER MINOR TIGHT SPOTS INTERMITTENTLY FROM 7,106' TO 9,147'. SOFT MILLING/WASHING TO 9,428'. STOP MILLING @ HARD PACK @ 9,428'. (BOTTOM OF HR/HZ @ 9,419'). - PUMP 5 bbl XCD POLYMER SWEEP TO REMOVE SUSPENDED SOLIDS. POH WITH MILL & PDM. - RIH W/2.5" SWIRL JET NOZZLE, EXTENSION & DBLCV. TAG BOTTOM @ 9,420'. SPOT 18.5 bbls IN PERFORATED INTERVAL F/9,419~ T/8,698w. ACID SOAK PERFORATIONS FOR 30 mins. - MIX/PUMP 5 bbls XCD POLYMER SWEEP. DISPLACE SWEEP TO SURFACE, TAKING ALL LOW Ph FLUIDS TO SURGE TANK WHILE HOISTING NOZZLE TO EOIT TO CHASE SWEEP. H2s @ <200ppm. - BEGIN JET ACID WASH WITH NOZZLE F/EOIT @ 8,973' T/9,420'. WASHING DOWN @ 20 fpm & i bpm PUMP RATE. PUMP 5 bbl SWEEP & DISPLACE WITH 140+ bbls FIW TO OBTAIN SUFFICIENT CLARITY FOR INJECTION. PREPARE TO SQUEEZE ACID. 10/13/91 - SPOT 22.7 bbls 7.5% HCL ACID TO EOCT. CLOSE CT RAMS, PROD WING VALVE,FLOW TEE & MONITOR CSG PRESSURE. PUMP ADDITIONAL 37.3 bbls 7.5% HCL FOR TOTAL SQUEEZE VOLUME OF 60 bbls. PUMP 85 bbls FIW TO OVERDISPLACE ACID TO FORMATION. - TUBING/CASING INTEGRITY WAS GOOD. - FINAL SQUEEZE PRESSURE WAS < 2500# @ 41 gpm. ISIP = 2500#, 5 min SIP = 2250#, 10 min FSIP = 2150#. RECEIVED DEC 20 t991 Alaska Oil & Gas Cons, Commission Anchorage DAILY REPORT WELL= C34-23 10/13/91 - RELEASE WELL PRESSURE. POH WITH CT JET NOZZLE (CONT'D) ASSEMBLY. * PUMP 256 bbls OF HCL CONTAMINATED RETURN FLUID FROM DECK SURGE TANK TO C44-14 DISPOSAL WELL. INJ RATE = 3.5 bpm @ 1600#. DISPLACE COMPLETION FLUID TO FORMATION WITH 100 bbls FIW. ISIP ON DISPOSAL WELL AFTER DISPLACEMENT WAS 9009. NOTE: DISPOSAL RATES OF 5.5 bpm @ 2000# WERE OBTAINED. THE REDUCED RATE WAS REQUIRED DUE TO PIPING PROBLEMS WHICH ARE CURRENTLY BEING RECTIFIED. * COIL TUBING EQUIP. RELEASED TO C24-14 @ 1200 hrs. RECEIVED DE(; 20 199! Alaska Oil A Gas Cons. Commission Anchorage Shell .Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 August 7, 1991 Ms. Joan Miller State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99502 Dear Ms. Miller: SUBJECT: MONTHLY INJECTION REPORT FOR THE MIDDLE GROUND SHOAL FIELD (MGS) FOR THE MONTH OF JULY, 1991 The Monthly Injection Report for the Waterflood project at MGS for July is enclosed in duplicate. If you have any questions regarding this report, please call Ms. Susan Murnan at (907) 263-9614. Very truly yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/slm Enclosures Sas \AOGCC\MTHLYINJ. JULY January-99 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 '-.:"i ::i ::i i ili iiiiiiii::ii!::i::iiiii::i::iii ii ACT ACT ACT ACT ACT ACT ACT ACT iii~ ~i~iiiii!iiil INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU 0 l-Jan-99 1357 3200 3125 978 700 660 386 3500 3500 1841 3500 0 0 0 0 0 0 400 0 0 550 0 1200 75 02-Jan-99 1340 3200 3125 967 700 660 383 3500 3500 1811 3500 0 0 0 0 0 0 400 0 0 550 0 1200 75 03-Jan-99 300 3200 3125 368 700 660 85 3500 3500 487 3500 0 0 0 0 0 0 400 0 0 550 0 1200 75 04-Jan-99 0 3200 312~ 0 700 660 0 3500 3500 0 3500 0 0 0 0 0 0 40¢ 0 0 550 0 1200 75 05-Jan-99 0 2000 2001] 0 575 575 0 1600 1600 0 1275 0 0 0 0 0 0 400 0 0 550 0 1050 80 06-Jan-99 0 2000 20013 0 575 575 0 1600 1600 0 1275 0 0 0 0 0 0 400 0 0 550 0 1025 80 07-Jan-99 1220 3100 30013 677 700 630 347 3500 3500 1533 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 08-Jan-99 1431 3100 30013 915 700 630 411 3500 3500 1888 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 09-Jan-99 1352 3100 30013 907 700 630 339 3500 3500 1845 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 10-Jan-99 1300 3150 30513 896 700 640 407 3500 3500 1799 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 1 l-Jan-99 1351 3150 305~ 511 700 640 386 3500 3500 1825 3500 0 0 0 0 0 0 400 0 0 550 0 1800 0 ~2-Jan-99 1332 3150 30513 744 700 640 438 3500 3500 1826 3500 0 0 0 0 0 0 400 0 0 550 0 1050 0 1824 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 Jan-99 1327 3200 31013 755 700 640 426 3500 3500 · .-,-Jan-99 1325 3200 31013 751 700 640 80 3500 3500 1832 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 15-Jan-99 1334 3200 31013 752 700 640 0 3500 3500 1856 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0 16-Jan-99 1334 3200 31013 754 700 640 45 3500 3500 1856 3500 0 0 0 0 0 0 400 0 0 550 0 2050 0 17-Jan-99 1337 3200 31013 754 700 640 417 3500 3500 1858 3500 0 0 0 0 0 0 400 0 0 550 0 1750 0 18-Jan-99 1329 3200 31013 753 700 640 432 3500 3500 1856 3500 0 0 0 0 0 0 400 0 0 550 0 1750 0 19-Jan-99 1329 3200 31013 756 700 640 415 3500 3500 1863 3500 0 0 0 0 0 0 400 0 0 550 0 1300 0 20-Jan-99 1339 3200 31013 755 700 640 419 3500 3500 1886 3500 0 0 0 0 0 0 400 0 0 550 408 3500 0 21-Jan-99 1341 3200 31013 757 700 640 421 3500 3500 1903 3500 0 0 0 0 0 0 400 0 0 550 156 3500 0 22-Jan-99 1348 3200 31513 759 700 630 419 3500 3500 1897 3500 0 0 0 0 0 0 400 0 0 550 57 3500 0 23-Jan-99 279 2200 24013 254 650 590 ~92 1700 1725 409 1000 0 0 0 0 0 0 400 0 0 550 0 1825 35 24-Jan-99 0 2150 24013 0 650 590 0 1700 1725 0 1000 0 0 0 0 0 0 400 0 0 550 0 1500 35 25-Jan-99 0 2150 2050 0 650 590 0 1600 1600 0 1000 0 0 0 0 0 0 400 0 0 550 0 1500 85 26-Jan-99 829 3200 20513 392 700 590 245 3500 1600 1222 3500 0 0 0 0 0 0 400 0 0 550 0 1100 85 27-Jan-99 1345 3200 31113 732 700 630 405 3500 3500 2125 3500 0 0 0 0 0 0 400 0 0 550 206 3500 0 28-Jan-99 1319 3200 3110 754 700 630 404 3500 3500 2141 3500 0 0 0 0 0 0 400 0 0 550 300 3500 0 29-Jan-99 1296 3200 3110 758 700 630 403 3500 3500 2121 3500 0 0 0 0 0 0 400 0 0 550 122 3500 0 30-Jan-99 1281 3200 3110 750 700 630 400 3500 3500 2117 3500 0 0 0 0 0 0 400 0 0 550 25 3500 0 3 l-Jan-99 1241 3200 3110 744 700 630 394 3500 3500 2071 3500 0 0 0 0 0 0 400 0 0 550 0 1625 0 TOTAL 31,916 18,893 8,599 45,692 0 0 0 1,274 MAXIMUM 3,200 3,150 700 660 3,500 3,500 3,500 0 0 0 0 400 0 550 3,500 85 __~ ERAGE 1,030 3,008 2,908 609 687 629 277 3,200 3,140 1,474 3,115 0 0 0 0 0 0 400 0 0 550 41 2,359 23 DAYS 26 26 25 26 0 0 0 7 u2/10/99 All injectors down January 4, 5 & 6 due to waterflood turbine annual maintenance. All injectors down January 24 & 25 due to waterflood turbine annual maintenance. D ~.~ ,~e'~ ~,~ ! ~./ g ~.,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY 'INJECTION REPORT 2O AAC 25.432 SHELL WESTERN E&P INC. Name of Operator MIDDLE GROUND SHOAL Field and Pool JULY, 1991 Month and Year of Injection TUBING PRESSURE 1. 2. 3. 4. 5. 6. 7. Yell # API# CLass Field & Days in MAX Average 50- Pool Code Operation PSIG PSIG A 11-12 733-10083-00 W 524114 31 3,550 3,502 A 11-13 733-20007-01 W 524114 31 3,550 3,502 A 12-12 733-20044-00 W 524114 31 3,550 3,502 A 23-01 733-20238-00 ~ 524114 31 3,550 3,502 A 33-14 733-20057-00 W 524114 31 3,550 3,502 A 34-11 733-10084-01 ~ 524114 31 4,400 4,348 A 34-14 733-10086-01 W 524114 31 3,550 3,500 A 44-11 733-20027-00 W 524114 0 N/A N/A · C 23-26 733-20071-00 W 524114 31 3,500 3,500 C 24-23 733-20145-01 W 524114 31 3,500 3,500 C 34-23 733-20041-00 ~ 524114 0 1,050 1,050 C 41-23 733-20163-00 ~ 524114 31 3,200 3,200 C 41-26 733-20409-01 W 524114 31 3,500 3,500 CASING PRESSURE 8. 9. MAX . Average PSIG PSIG DAILY AVERAGE INJECTION TOTAL MONTHLY INJECTION 11. 12. 13. Gas Liquid Gas (MCF) (BBL) (MCF) 10. Liquid (BBL) 27,404 10,349 18,024 100 67 884 80 46 334 3,300 3,250 581 38,547 41,219 6,066 21,085 0 120 63 1,243 95 48 1,330 24 20 196 170 107 680 100 86 0 3,209 22,661 0 75,844 4,837 3,475 3,451 104 3,500 3,069 731 1,050 1,050 0 0 0 2,450 0 0 157 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~ Title: Manager Alaska Operations Date: ~~// Total 269,245 For~ 10-406 Rev. 12-1-85 Submit in Duplicate LOTUS\MTHLYINJ\JULY-RPT.WI(5 RECEIVED AUG 1 2 1991 Alaska Oil a 6as Cons. Commissian STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CC~MISS[ON MONTHLY iNJECTION REPORT 2O &AC 25.432 SHELL WESTERN E&P INC. Name of Operator MIDDLE GROUND SHOAL Field and Pool JULY, 1~1 Month and Year of injection 1. WeLL # TUBING PRESSURE 2. 3. 4. 5. 6. 7. APl # CLass FieLd & Days in MAX Average 50- Pool Code Operation PSIG PSIG 733-10083-00 W 524114 31 3,550 3,502 733-20007-01 W 524114 31 3,550 3,502 733-20044-00 W 524114 31 3,550 3,502 733-20238-00 W 524114.. 31 3,550 3,502 733-20057-00 W 524114 31 3,550 3,502 733-10084-01 ~ 524114 31 4,400 4,348 733-10086-01 W 524114 31 3,550 3,500 733-20027-00 W 524114 0 N/A N/A 733-20071-00 W 524114 31 3,500 3,500 733-20145-01 ~ 524114 31 3,500 3,500 733-20041-00 ~ 524114 0 1,050 1,050 733-20163-00 W 524114 31 3,200 '3,200 733-20409-01 ~ 524114 31 3,500 3,500 A 11-12 A 11-13 A 23-01 A 33-14 A 34-11 A 34-14 · A 44-11 : c 23-26 C 24-23 C 34-23 C 41-23 C 41-26 CASING PRESSURE 8. 9. 10. MAX Average Liquid PSIG PSIG (BBL) TOTAL MONTHLY INJECTION 11. 12. 13. Gas Liquid Gas (MCF) (BBL) (MCF) DALLY AVERAGE iNJECTION 27,404 10,349 18,024 38,547 41,219 100 67 80 46 334 3,300 3,250 581 120 63 1,243 95 48 1,330 6,066 21,085 0 3,209 22,661 0 75,844 4,837 24 20 196 170 107 680 100 86 0 3,475 3,451 104 3,500 3,069 731 1,050 1,050 0 0 0 2,450 0 0 157 hereby certify that the foregoing is true and correct to the best of my knowLedge. Signed~ .- TitLe: Manager ALaska Operations Date: =~-~// Total 269,245 Form 10-406 Rev. 12-1-85 RECEIVED AUG 1 2 1991 A/aska OiJ & Sas Cons Commissien aJ orage Submit in DupLicate LOTUS\MTHLYINJ\JULY-RPT.WlC3 January-2002 DATE& NOTES 01 -Jan-2002 02-Jan-2002 03-]an-2002 04-.Ian-2002 05-.lan-2002 06-Jan-2002 07-Jan-2002 08-Jan-2002 09-~an-2002 I O-Jan-2002 ! !-Jan-2002 12-Jan-2002 13-Jan-2002 14-Jan-2002 15-Jan-2002 16-Jan-2002 17-Jan-2002 18-Jan-2002 19-Jan-2002 20-Jan-2002 2 ! -Jan-2002 22-Jan-2002 23-$an-2002 24-Jan-2002 25-Jan-2002 26-Jan-2002 27-1an-2002 28-Jan-2002 29-1an-2002 30-Jan-2002 31 -$an-2002 TOTAL MAXIMUM AVERAGE # DAYS 02/11/2002 C23-23 ACT ]NJ ]NJ ANNU ~07'~3450 1977 3450 2010 3450 275 3450 2219 3400 2046 34OO 2045 3450 2039 3450 1978 3450 2028 3425 2027 3425 1964 3425 1926 3400 1941 3400 1962 3400 1982 3400 1320 3400 1991 3425 1966 3425 1897 3425 1949 3425 1864 3425 1928 3425 1944 3425 1907 3425 1926 3425 1924 3425 1930 3425 1898 3425 1884 3450 58,771 3,450 1,896 3,426 31 WATER INJECTION REPORT PLATFORM C C41-23 ACT ]NJ ]NJ ANNU C24-23 ACT 0 1800 2( 0 1800 0 1800 0 1800 0 570 57( 0 570 57( 0 570 5~I 0 570 5 0 570 5771 0 570 5 0 570 570 0 570 570 0 570 570 0 570 570 0 57O 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 575 575: 0 580 580 0 580 58(~ o 55o 55~ 0 580 580 0 580 588~ 0 580 5 0 580 58~ 0 580 58 , 0 580 58~ 0 8,412 580i 3,450 3,450 1,800 0 732 5021 271 2,934 2,929 0 I 26 383 3450 34~ 330 3450 345~ 0 3450 34~ 0 3450 345~ 0 1150 115(3 0 1150 115(3 0 1150 115(3 85 i150 115~ 364 1150 115~ 359 3300 309 3300 330~ 232 3300 330~ 231 3300 330~ 265 2800 280~ 351 2800 280~ 350 3275 325~ 352 3275 325(3 228 3275 325~ 354 3275 325(3 350 3300 3275 343 3300 3275 348 3275 3275 341 3275 3275 349 3275 3275 351 3275 3275 347 3275 3275 351 3275 3275 349 3275 3275 349 3275 3275 346 · 32753275 395 3425 '3425 C34-23 ACT ]NJ ]NJ ANNU 1578 3100 305C 1558 3100 305( 1597 3100 305( 212 3100 305( 1 643 3050 300( 1585 3050 300( 1591 3100 305( 1597 3100 305( 1563 3100 305( 1574 3100 305( 1598 3100 305( 1595 3100 305( 1559 3100 305( 1546 3100 3025 1557 3100 302.~ 1564 3100 3025 1573 3100 3025 986 3100 3025 1589 3100 302~ 1577 3075 302.~ 1529 3075 302.~ 1566 3075 302.~ 1529 3075 3025 1551 3075 302.~ ! 563 3075 3025 1533 3075 302.~ 1559 3075 3025 1556 3075 302.~ 1558 3075 302~ 1537 3075 3025 1511 3100 302-~ 46,634 3,100 3,05(] 1,504 3,088 3,032 31 C23-26 ACT ]NJ INJ ANNU 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 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT ]NJ ]NJ ANNU 0 700 0 700 60f 0 700 60~ 0 700 6(X 0 800 625 0 800 62~ 0 800 625 0 800 62~ 0 800 '625 0 800 625 0 800 625 0 800 625 0 800 625 0 800 62.~ 0 800 625 0 800 62.~ 0 795 625 0 795 62.~ 0 790 62.~ 0 790 65( 0 ' 790 65( 0 790 65( 0 790 65( 0 790 65( 0 790 65C 0 790 65( 0 79O 65( 0 790 65( 0 790 65( 0 790 65C 0 850 65( 0 0 850 65~ 0 0 785 631 C44~14RD ACT ]NJ ]NJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 958 1,800 550 0 0 575 0 0 550 0 0 550 0 0 55O 380 1,300 550 0 0 550 0 0 550 350 1,300 550 0 0 550 360 1,200 550 0 0 550 390 1,550 550 0 0 550 0 0 550 356 1,800 550 0 0 550 0 0 550 330 1,500 55O 0 0 550 309 1,400 550 0 0 575 0 0 550 210 1,300 550 0 0 560 324 1,300 570 0 0 55O 3,967 1,800 575 128 466 553 C24A-23 ACT 1NJ INJ ANNU 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60~ 0 0 0 0 60~ 0 0 60~ 0 0 60~ 0 0 0 0 60~ 0 0 60~ 0 0 0 0 60~ 0 0 0 0 60~ 0 0 ~0~ 0 0 60~ 0 0 0 0 60~ 0 0 0 0 0 0 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60~ 0 0 6~ 0 0 60~ 0 0 60O 0 0 600 C24A-14 ACT ]NJ ]NJ ' ANNL 0 2750 0 2750 0 2750 0 2750 0 2000 0 2000 0 1700 140 1600 306 1600 268 3450 258 3450 252 3450 235 3450 229 3500 234 3500 284 3500 498 4470 456 4470 433 4550 419 4550 410 4550 413 4550 376 4550 368 4550 252 3100 31 4100 449 4100 306 4100 392 14100 370 4100 352 4400 7,731 4,550 249 3,498 0 i0 0 24 241-23 shut in due to annular communication problem. 234-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99= 224A-23 shut in for field study and evaluation per Doug Marshall. WATER INJECTION REPORT PLATFORM C December-2001 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 ACT ACT ACT ACT ACT ACI' ACI' ACT ACT DATE & NOTES INJ INS ANNU INS INJ ANNU INJ 131J ANNU INI INJ ANNU INJ INJ ANNU INJ INJ ANNU 13/I INJ ANNU INS INI ANNU INJ IAI~ __ OI-Dec-2001 2070 3425 (~ 0 565 56f. 370 3450 345(~ 1538 3100 305C 0 0 0 0 760 60(] 0 0 55(] 0 0 60~ 318 4600 02-Dec-2001 2054 3425 (] 0 565 56.~ 368 3450 345(~ 1533 3100 305~ 0 0 0 0 760 60~ 0 0 .550 0 0 60(3 326 4600 C 03-Dec-2001 2057 3425 (~ 0 565 56~ 369 3450 345(~ 1538 3100 305( 0 0 0 0 760 60~ 0 0 55(3 0 0 60~ 323 4600 04-Dec-2001 2053 3425 (] 0 565 56.~ 369 3450 345( 1537 3100 305~ 0 0 0 0 760 600 0 0 55(] 0 0 600 322 4600 C 05-Dec-2001 2032 3425 (] 0 565 565~ 366 3450 345(] 1526 3100 305( 0 0 0 0 760 600 0 0 55(] 0 0 600 319 4600 C 06-Dec-20Ol 2067 3425 (] 0 565 56.~ 373 3450 34511 1549 3100 305~ 0 0 0 0 750 60~ 0 0 575 0 0 595 319 4450 07-Dec-2001 2051 3425 (] 0 565 56.s 371 3450 345(] 1545 3100 305( 0 0 0 0 750 60(1 0 0 55(] 0 0 595 323 4450 C 08-Dec-2001 2055 3425 (] 0 565 56.~ 371 3450 345~ 1550 3100 305~ 0 0 0 0 750 60~ 0 0 55(] 0 0 595 317 4450 C 09-Dec-2001 2044 3425 (] 0 565 575~ 367 3450 345~ 1546 3100 305~ 0 0 0 0 750 600 0 0 55(1 0 0 595 266 4500 10-Dec-2001 2042 3440 (] 0 550 371 3450 345(~ 1548 3100 305( 0 0 0 0 770 60~ 0 0 55(] 0 0 600 370 4600 C 1 l-Dec-2001 2064 3440 (] 0 550 57( 376 3450 345(~ .1568 3100 305( 0 0 0 0 770 60(3 0 0 55(3 0 0 600 319 4550 ( 12-Dec-2001 1998 3450 ( 0 550 57( 369 3450 345(] 1543 3100 305( 0 0 0 0 770 60(3 0 0 55(] 0 0 600 0 3000 13-Dec-2001 266 3450 ( 0 550 57( 62 1300 135( 203 1550 152~0 0 (] 0 770 60~ 0 0 55(] 0 0 595 0 2600 C 14-Dec-200 ! 2323 3450 (] 0 550 57{~ 403 3500 350~ 1651 3100 305( 0 0 0 0 770 60(3 0 0 55(] 0 0 595 349 4250 C 15-Dec-2001 2103 3400 ( 0 550 570 378 3450 345(1 1590 3100 305( 0 0 0 0 770 60~ 0 0 55(] 0 0 595 392 4500 C 16-Dec-2001 2092 3400 (~ 0 550 57( 382 3450 345(] 1582 3100 30~ 0 0 0 0 770 60~ 0 0 55(] 0 0 595 372 4525 C 17-Dec-2001 2120 3400 (~ 0 550 570 388 3450 345( 1601 3100 305C 0 0 (] 0 770 60(] 0 0 55(] 0 0 595 359 4525 C 18-Dec-2001 2097 3400 (~ 0 550 570 387 3450 345~ 1593 3100 305~ 0 0 (] 0 770 60~ 0 0 55(] 0 0 595 248 4525 19-Dec-2001 2091 3450 ( 0 550 570 384 3450 345{1 1594 3100 305C 0 0 0 0 780 60~ 0 0 55(] 0 0 595 377 4550 C 20-Dec-2001 2067 3450 £0 20 20 381 3450 345( 1583 3100- 305C 0 0 0 0 785 60~ 0 0 55C 0 0 595 351 4600 C 2 l-Dec-2001 2072 3450 C 0 1300 20 380 3450 345(1 1586 3100 305C 0 0 (] 0 790 60~ 0 0 55(~ 0 0 595 322 4600 C 22-Dec-2001 2046 3450 C 0 1800 20 375 3450 345(~ 1570 3100 305C 0 0 (~ 0 785 60~ 0 0 55(~ 0 0 595 305 4600 C 23-Dec-2001 2073 3450 C 0 950 20 382 3450 345(1 1590 3100 305C 0 0 (] 0 785 60~ 0 0 55(] 0 0 595 297 4600 C 24-Dec-2001 2059 3450 C 0 500 20 379 3450 345( 1581 3100 305C 0 0 (] 0 765 60~ 0 0 55fl 0 0 595 310 4500 C 25-Dec-2001 2027 3450 C 0 650 20 370 3450 345C 1558 3100 305C 0 0 0 0 780 60~ 0 0 55{~ 0 0 595 319 4500 26-Dec-2001 2076 3450 ( 0 1800 20 381 3450 345(1 1596 3100 305C 0 0 (] 0 700 60~ 0 0 575 0 0 595 324 4500 C .27-Dec-200 i 2049 3450 C 0 1800 20 377 3450 345( 1573 3100 305C 0 0 1~ 0 700 60~ 0 0 55(~ 0 0 595 320 4500 C 28-Dec-2001 2058 3450 C 0 1800 20 378 3450 34~5( 1576 3100 305( 0 0 (] 0 700 60~ 0 O 55(] 0 0 595 312 4500 ( 29-Dec-2001 2038 3450 C 0 1800 20 374 3450 345(1 1565 3100 305C 0 . 0 (] 0 700 60~ 0 0 56(~ 0 0 595 309 4500 C 30-Dec-2001 1922 3450 ( 0 1800 20 355 3450 345(~ 1483 3100 305( 0 0 (] 0 700 60(3 0 0 57(3 0 0 595 304 4500 31 -Dec-2001 1837 3450 C 0 1800 20 362 3450 345( 1437 3100 305( 0 0 0 0 700 60~ 0 0 595 234 4500 TOTAL 62,003 0 11,318 47,033 0 0 0 0 9,326 MAXIMUM 3,450 (] 1,800 570! 3,500 3,500 3,100 3,05(] 0 0 790 600 0 575 0 600 4,600 0 AVERAGE 2,000 3,436 (] 0 858 356 365 - 3,382 3,384 1~517 3,050 3,001 0 0 0 0 755 600 0 0 553 0 0 596 301 4,415 0 #DAYS 31 0 31 .31 0 0 0 01/15/2002 0 29 -. C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject ~ecelved from Mr. Wondzell on 12/14/99. C24A-23 shut in for field study and evaluation per Doug Marshall. . WATER INJECTION REPORT PLATFORM C __ November-2001 C23-23 C41-23 C24.23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A-14 AC3' ACT ACT ACT ACT ACT ACT AC'F ACT DATE & NOTES INJ ll~l ANNU INJ INJ ANNU! INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ AN~ INJ IN'J __ 01-Nov-2001 2004 3450 ~ 0 555 555 371 3450 3450 1508 3100 306( 0 0 0 0 745 59( 0 0 55~ 0 0 60( 337 4500 02-Nov-2001 2032 3450 0 555 555 377 3450 345~ 1523 3100 306( 0 0 0 0 745 590 0 0 55~ 0 0 60( 335 4500 04-Nov-200 ! 2022 3450 0 0 555 555 374 3450 345~ 1522 3100 0 0 {3 0 745 0 0 55~ 0 0 60( 343 4500 05-Nov-2001 2029 3450 0 0 555 555 374 3450 345(] 1524 3100 3060 0 0 0 0 745 5~ 0 0 55~ 0 0 60( 341 4500 06-Nov-2001 2014 3450 0 0 555 555 374 3450 345~ 1516 3100 3060 0 0 {3 0 745 5 0 0 575 0 0 60( 334 4500 07-Nov-2001 2010 3450 0 0 555 555 370 3450 345~ 1511 3100 3060 0 0 0 0 745 59( 0 0 55~ 0 0 60( 320 4500 08-Nov-2001 2028 3450 0 0 555 555 373 3450 345~ 1526 3100 3060 0 0 (3 0 745 59( 0 0 55~ 0 0 60~ 313 4500 09-Nov-2001 2012 3450 0 0 550 560 365 3450 345~ 1511 3100 38~ 0 0 0 0 750 60( 0 0 55C 0 0 60( 301 4450 10-Nov-2001 2035 3450 0 0 550 560 365 3450 345~ 1510 3100 3 0 0 {3 0 750 60( 0 0 55~ 0 0 60~ 307 4450 ! l-Nov-2001 2079 3450 0 0 550 560 370 3450 345~ 1532 3100 305( 0 0 {3 0 750 60( 0 0 55{~ 0 0 60~ 309 4450 12-Nov-2001 2075 3450 0 0 560 565 366 3450 345(3 1527 3100 305(~ 0 0 0 0 750 60( 0 0 55{3 0 0 60C 305 4425 ! 3-Nov-2001 2114 3450 00 560 565 372 3450 345~ 1543 3100 3050 0 0 {3 0 750 60( 0 0 55~ 0 0 60~ 306 4425 14-Nov-2001 2093 3450 0 0 560 565 365 3450 345(3 1528 3100 305( 0 0 0 0 750 6iX 0 0 55{3 0 0 60C 292 4425 15-Nov-200 ! 2104 3450 0 0 560 565 366 3450 345~ 1532 3100 305( 0 0 0 0 750 60( 0 0 55(3 0 0 60C 292 4400 ! 6-Nov-2001 2117 3450 0 0 560 565 370 3450 345{3 1541 3100 305{] 0 0 0 0 750 6(K 0 0 55(3 0 0 60~ 301 4400 17-Nov-2001 2098 3450 0 0 560 565 365 3450 345~ 1527 3100 3050 0 0 0 0 750 60( 0 0 55(3 0 0 60C 297 4400 ! 8-Nov-2001 2096 3450 0 0 560 565 369 3450 3450 1533 3100 305( 0 0 0 0 750 60( 0 0 550 0 0 60~ 308 4400 19-Nov-2001 2102 3450 0 0 560 565 · 367 3450 345C 1531 3100 3050 0 0 0 0 750 60( 0 0 55(3 0 0 60~ 310 4400 20-Nov-2001 2100 3450 0 0 560 565 367 3450 345(3 1523 3100 305( 0 0 0 0 750 60C 0 0 550 0 0 600 310 4400 2 l-Nov-2001 2081 3450 0 0 560 565 362 3450 345~ 1515 3100 305( 0 0 0 0 750 60~ 0 0 550 0 0 60~ 305 4450 22-Nov-2001 2103 3450 ~ 0 565 565 366 3450 345(3 I529 3100 306( 0 0 0 0 760 6(K 0 0 550 0 0 60~ 310 4475 23-Nov-2001 2115 3450 0 565 565 369 3450 345(31533 3100 306( 0 0 0 0 760 6(K 0 0 550 0 0 60~ 309 4475 24-Nov-2001 2129 3450 I 0 565 565 369 3450 345(3 1541 3100 306( 0 0 0 0 760 60~ 0 0 550 0 0 60~ 310 4475 25-Nov-2001 2142 3450 0 565 565 370 3450 345(3 1549 3100 306( 0 0 0 0 760 60~ 0 0 550 0 0 60(3 309 4475 26-Nov-2001 2116 3450 ~ 0 570 570 367 3450 345(3 1532 3100 306( 0 0 0 0 760 60~ 0 0 575 0 0 60~ 301 4450 27-Nov-2001 2034 3450 0 570 570 364 3450 345(31501 3100 306( 0 0 0 0 760 60~ 0 0 550 0 0 60(] 273 4450 28-Nov-2001 2096 3425 I 0 565 565 373 3450 345(3[ 1547 3100 305( 0 0 0 0 760 60C 0 0 550 0 0 60(3 339 4600 29-Nov-2001 2069 3425 0 565 565 368 3450 34501532 3100 305( 0 0 0 0 760 60C 0 0 560 0 0 600 324 4600 30-Nov-2001 2067 3425 0 0 565 565 369 3450 345(3 1537 3100 305( 0 0 0 0 760 60C 0 0 570 0 0 60~ 321 4600 TOTAL 62,135 ~ 0 11,072 45,800 0 0 0 0 9,402 MAXIMUM 3,450 570 57£ 3,450 3,450 3,100 3,06(3 0 0 760 600 0 575 0 600 4,600 AVERAGE 2,071 3,448 0 560 562 369 3,450 3,450 1,527 3,100 3,055 0 0 0 0 752 597 0 0 553 0 0 600 313 4,469 # DAYS 30 0 30 30 0 0 0 12/12/200 ! 0 30 'C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr, Wondzell on 12/14/99. C24A-23 shut in for l'mld study and evaluation pet Doug Marshall. October-2001 C23-23 01-Oct-2001 02-Oc~-2001 03-Ocl-2001 04-Oct-2001 05-Oc~-200 1 06-Oct-200 ! 07-Oct-2001 08-Oct-2001 09-Oct-200! 10-Oct-200 ! 11-Oc1-2001 ! 2-Oc~-2001 13-Oct-2001 14-Oct-2001 15-Oct-2001 16-Oct-2001 17-Oct-2001 18-Oct-2001 19-Oct-2001 20-Oct-2001 21-Oct-2001 22-Oct-2001 23-Oct-2001 24-Oct-2001 25-Oct-2001 · 26-Oct-2001 27-Oct-2001 28-Oct-2001 29-Oct-2001 30-Oct-2001 31 -Oct-2001 TOTAL MAXIMUM AVERAGE # DAYS 2077 340O 2084 34OO 2082 34OO 2071 3400 1290 3400 783 3400 2254 3400 2128 3400 2O56 34OO 1906 34O0 0 34OO 762 3350 0 3350 2189 3350 2126 3400 2089 3400 1992 3400 ! 942 3400 1952 3400 1336 3400 2020 3400 2001 3400 2OO9 34OO 2003 3400 2011 3400 2010 34OO 2029 3400 1963 3450 1963 3450 2007 3450 55,079 3,450 1,777 3,400 29 11113/2001 WATER INJECTION REPORT PLATFORM C C41-23 C24-23 C34-23 C23-26 ACT ACT ACT ACT INS INS ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU 381 3450 346~ 388 3450 346(1 384 3450 346~ 380 3450 346(1 236 3450 346~ 150 3450 345(1 390 3450 34.% 381 3450 34.% 370 3450 345(3 0 3450 34.% 0 3450 34.% 399 3450 34.% 398 3450 34.% 397 3450 345( 388 3450 34.% 378 3450 34.% 384 3450 34.% 261 3450 345( 383 3450 34.% 377 3450 34.% 379 3450 34.% 373 3450 34.% 373 3450 34.% 380 3450 34.% 371 3450 345¢ 389 3450 345(3 374 3450 345¢ 372 3450 34.% 375 3450 34.% 1521 3150 315( 1545 3150 315( 1542 3150 312~ 1530 3150 312~ 955 3150 312~ 540 3100 305( 1579 3100 305( 1556 3100 305( 1521 3100 305( 1430 3100 305( 0 3100 3O5( 517 3000 300( o ~ ~ 1572 3000 1565 3100 3050 1556 3100 3050 1513 3100 3050 1490 3100 3050 1490 3 ! 003050 1019 3100 3o50 1500 3100 3050 1530 3100 3050 1538 3100 3050 1530 3100 3050 1531 3100 3055 1534 3100 30551 ! 504 3100 3055 1568 3100 3055 1508 3100 3060 1496 3100 3060 1518 3100 3060 41,198 3,150 3,150: 1,329 3,098 3,060 29 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 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C24A- 14 C4 ! -26 C44-14RD C24A-23 ACT ACT ACT ACT INJ INJ ANNU INJ INJ ANNU INJ INJ ANNt INJ INJ. ANNE 0 735 55( 0 735 55{ 0 735 55( 0 735 55( 0 735 55( 0 735 0 735 55{ 0 735 55( 0 735 55( 0 735 55( 0 735 55{ 0 730 55( 0 730 551 0 730 55 0 730 56~ 0 730 560 0 730 55~ 0 730 0 730 560 0 730 560 0 730 560 0 730 56~ 0 730 560 0 730 560 0 745 575i 0 745 575 0 745 575 0 745 59( 0 745 59( 0 745 59( 0 745 59(~ 10,310 3,450 3,46~ 333 3,450 3,452 29 550 56( 550 56( 56O 56( ~ 5~ 500 ~0 56o 560 56O 560 560 560 560 56O 560 560 56O 56O 550 560 550 560 550 560 570 570 570 57O 570 570 57O 57O 570 570 570 570 570 570 570 570 570 570 570 570 570 570 570 570 570 570 570 570 570 570 570 570 555 555 570 570 563 565 0 0 550 0 0 550 0 0 55(] 0 0 55(] 0 0 551] 0 0 575 0 0 55(] 0 0 55~ 0 0 551] 0 0 55(3 0 0 550 0 0 55(] 0 0 55~ 0 0 55(3 0 0 55(] 0 0 550 0 0 55C 0 0 550 0 0 550 0 0 55(3 0 0 550 0 0 55~ 0 0 550 0 0 550 0 0 55(3 0 0 575 0 0 550 0 0 550 0 0 56~ 0 0 570 0 0 598 0 0 598 0 0 600 0 0 6OO 0 0 6O0 0 0 6OO 0 0 6OO 0 0 6OO 0 0 6O0 0 0 6OO 0 0 600 0 0 6OO 0 0 600 0 0 600 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 6OO 0 0 60O 0 0 600 0 0 6OO 0 0 6OO 0 0 6O0 0 0 60O 0 0 6OO 0 0 598 0 0 0 745 590l 0 575 0 735 561! 0 0 553 0 ! 0 248 4450 145 4450 72 2575 433 2575 12£ 240 2575 12C 86 4300 442 4300 lC 385 4300 387 4450 lC 342 4450 lC 0 4450 0 2400 14~ 0 2400 269 2000 23£ 500 4450 439 4450 353 445O 34O 445O 228 4450 0 4450 385 4450 37O 445O 351 4500 340 4500 33O 450O 345 4500 33O 4500 333 4500 340 4500 8,888 4,500 230 287 4,054 30 27 U41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AC)GCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. WondzeH on 12/14/99. C24A-23 shut in for field study and evaluation per Doug Marshall. WATER INIECTIOIV REPORT PLATFORM C __ September-2001 C23-23 C4 ! -23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 ~ ACT ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES INJ ]~J ANNU INJ INJ ANNU INS INS ANNU INS INS ANNU INS INS AHNU INJ INS ANNU IN`/ INJ ANNU INJ INJ ANNU INJ INS ANNU __ 01-Sep-2001 2179 3400 0 0 500 530 374 3400 345( 1567 2850 3100 0 0 (~ 0 710 510 0 0 550 0 75 58'~ 370 4500 (3 02-Sep-2001 1627 3400 00 500 530 292 3400 345( 1185 2850 3100 0 0 (~ 0 710 510 0 0 550 0 75 585 339 4500 13 03-Sep-2001 2262 3400 00 500 540 37'7 3400 345(1582 2850 3100 0 0G 0 710 550 0 0 550 0 0 585 335 4500 (3 04-Sep-200 ! 2199 3400 00 500 540 366 3400 345( 1553 2850 3100 0 0 0 0 710 55(3 0 0 550 0 0 585 337 4500 (3 05-Sep-2001 2223 3400 00 500 540 372 3400 345( 1566 2800 3100 0 0 0 0 710 550 0 0 550 0 0 585 344 4450 06-Sep-2001 2228 3400 00 5(}0 54~ 372 3400 345( 1560 2850 3100 0 0 0 0 710 550 0 0 575 0 0 57C 346 4450 (3 07-Sep-2001 2247 3400 00 550 54(3 375 3400 345( 1567 2800 3100 0 0 0 0 710 550 0 0 550 0 0 585 341 4450 13 08-Sep-2001 2253 3400 0 0 500 54(3 374 3475 345( 1563 2850 3100 0 0 0 0 735 550 0 0 550 0 0 585 337 4400 (3 09-Sep-2001 2260 3400 0 0 540 550 374 3475 345( 1562 2850 3100 0 0 0 0 710 550 0 0 550 0 0 585 339 4400 I 0-Sep-2001 2264 3400 0 0 540 50C 371 3450 345( 1556 2850 3100 0 0 0 0 710 55(3 0 0 550 0 0 585 341 4400 ! l-Sep-2001 2264 3400 00 540 550 371 3450 347.~1549 2850 3100 0 0 0 0 710 550 0 0 550 0 0 585 347 4400 12-Sep-2001 2264 3400 0 0 540 550 370 3450 347.' 1545 2850 3100 0 0 0 0 710 55(3 0 0 550 0 0 585 343 4400 13-Sep-2001 2251 3400 0 0 550 550 370 3450 342.' 1537 2850 3100 0 0 0 0 715 550 0 0 550 0 0 59~ 326 4400 2284 3400 0 0 550 55(3 376 3450 345(~ 1561 2850 3100 0 0 0 0 770 550 0 0 550 0 0 14-Sep-2001 59C 335 15-Sep-2001 2256 3400 0 0 550 550 373 3450 3450 1553 2850 3100 0 0 0 0 770 55(3 0 0 550 0 0 580 345 4400 16-Sep-2001 2251 3400 0 0 550 55C 373 3450 347.' 1551 2850 310C 0 0 0 0 770 550 0 0 550 0 0 585 360 4400 17-Sep-2001 2252 3400 0 0 550 55(3 374 3450 3475' 1552 2850 3100 0 0 0 0 770 550 0 0 550 0 0 585 361 4400 18-Sep-2001 2181 3400 0 0 550 5513 373 3450 3475 1534 2850 310C 0 0 0 0 770 5513 0 0 550 0 0 5813 337 4450 19-Sep-2001 2146 3400 0 0 550 550 377 3450 3475 1552 2850 310~ 0 0 0 0 770 5513 0 0 550 0 0 58C 352 4450 13 20-Sep-2001 2171 3400 0 0 550 55C 372 3450 3450 1531 2~50 310C 0 0 0 0 770 5513 0 0 550 0 0 59~ 339 4450 1 2 l-Sep-2001 2163 3400 0 0 550 550 371 3450 3450 1528 2850 310~ 0 0 0 0 770 55(3 0 0 550 0 0 59C 340 4450 1 22-Sep-2001 2184 3400 (3 0 550 55( 372 3450 345{ 1528 2850 310C 0 0 0 0 770 5513 0 0 550 0 0 59C 348 4450 1 23-Sep-2001 2189 3400 0 0 550 550 372 3450 3450 1530 3100 3i0c 0 0 0 0 770 55(3 0 0 550 0 0 595 350 4450 24-Sep-2001 2177 3400 (3 0 550 55C 372 3450 3450 1520 3100 310C 0 0 0 0 770 5513 0 0 550 0 0 595 342 4450 25-Sep-2001 2191 3400 0 0 550 55C 375 3450 3450 1528 3100 3i0c 0 0 0 0 770 5513 0 0 550 0 0 59-~ 342 4450 26-Sep-2001 2187 3400 (3 0 550 550 372 3450 3450 1518 3150 310C 0 0 0 0 770 5513 0 0 575 0 0 598 338 4450 27-Sep-2001 2196 3400 (3 0 550 56C 380 3450 34601537 3150 31513 0 '0 0 0 735 5513 0 0 550 0 0 599 331 4450 28-Sep-2001 2172 3400 (3 0 550 56~ 376 3450 3460 1530 3150 3150 0 0 0 0 735 5513 0 0 550 0 0 599 335 4450 13 29-Sep-2001 2146 3400 (3 0 550 56C 380 3450 3460 1543 3150 315C 0 0 0 0 735 5513 0 0 560 0 0 598 339 4450 30-Sep-2001 2138 3400 13 0 550 56C 376 3450 3460 1523 3150 3150 0 0 0 0 735 5513 0 0 570 0 0 599 342 4450 __ TOTAL 65,805 0 11,122 46,011 0 0 0 0 10,281 MAXIMUM 3,400 0 550 56(] 3,475 3,475 3,150 3,150 0 0 770 550 0 575 75 598 4,500 1 AVERAGE 2,194 3,400 0 0 537 54~ 371 3,440 3,456 1,534 2,922 3,107 0 0 0 0 740 547 0 0 553 0 5 588 343 4,440 0 __ # DAYS 30 0 30 30 0 0 0 0 30 10/15/2001 C4!~shut in due to annular communication problem. C34~23 hns developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. C24A-23 shut in for field study and evaluation per Doug Marshall. WATER INJECTION REPORT PLATFORM C August-2001 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 ACT ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES INJ INJ ANNU 1NJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU ~]J INJ ANNE 01-Aug-2001 2275 3400 0 0 490 49~ 387 3450 345{ 1569 2800 310( 0 0 0 0 495 30( 0 0 550 0 505 54~ 368 4500 02-Aug-2001 2276 3400 0 0 500 5 lC 388 3450 3450 ! 566 3500 310( 0 0 0 0 650 49C 0 0 550 0 505 54~ 246 4500 03-Aug-2001 2283 3425 0 0 500 51C 389 3450 3450 1564 3500 310( 0 0 0 0 650 50( 0 0 550 0 490 54.~ 395 4550 04-Aug-2001 2277 3400 0 0 500 50~ 388 3450 3450 1559 3500 310( 0 0 0 0 660 50~ 0 0 550 0 450 55( 375 4550 05-Aug-2001 226~ 3400 0 0 500 51C 386 3450 3450 1554 3500 310( 0 0 0 0 660 50( 0 0 550 0 425 55( 372 4500 06-Aug-2001 2274 3400 0 0 500 51¢ 389 3450 3450 1556 3500 310( 0 0 0 0 660 50( 0 0 575 0 400 55( 370 4500 07-Aug-2001 2269 3400 0 0 500 51C 391 3450 3450 1554 3500 310( 0 0 0 0 660 50~ 0 0 550 0 375 55~ 370 4500 08-Aug-200 ! 2258 3400 {3 0 500 51C 391 3450 3450 1555 2900 310( 0 0 0 0 670 50( 0 0 550 0 350 552 359 4500 09-Aug-2001 2299 3400 0 0 500 51C 390 3450 3450 1556 2900 310( 0 0 0 0 670 50~ 0 0 550 0 350 552 357 4500 10-Aug-2001 2324 3400 0 0 500 51C 389 3450 3450 1549 2~00 310( 0 0 0 0 670 50C 0 0 550 0 350 552 334 4500 ! l-Aug-2001 2334 3400 0 0 500 5 lC 391 3450 3450 ! 553 2900 310( 0 0 0 0 670 50~ 0 0 550 0 325 56~ 362 4500 12-Aug-2001 2334 3400 0 0 500 51C 390 3450 3450 1552 2900 310( 0 0 0 0 670 50~ 0 0 550 0 .325 5~ 363 4500 13-Aug-2001 2352 3400 0 0 500 51C 390 3450 3450 1549 2900 310( 0 0 0 0 670 50C 0 0 550 0 325 5~ 362 4500 14-Aug-2001 2341 3400 0 0 500 51C 390 3450 3450 1545 2900 310( 0 0 0 0 670 50(~ 0 0 550 0 325 56~ 365 4500 15-Aug-2001 2332 3400 0 0 500 51(~ 389 3450 3450 1540 2900 310( 0 0 0 0 670 50( 0 0 550 0 325 56~ 361 4500 16-Aug-2001 1640 3400 0 0 500 51E 286 3450 3450 1132 2900 310( 0 0 0 0 670 50~ 0 0 550~ 0 325 56(] 367 4500 17-Aug-2001 2300 3425. 0 0 500 47C 385 3475 3475 1602 2900 310~ 0 0 0 0 690 50~ 0 0 5501 0 250 53C 359 4550 18-Aug-2001 2267 3425 (3 0 500 47£ 381 3475 3475 1582 2900 310( 0 0 0 0 690 50~ 0 0 550~ 0 250 53~ 361 4550 19-Aug-2001 2269 3425 0 0 500 47¢ 381 3450 3450 1576 2850 310~ 0 0 0 0 690 50~ 0 0 55( 0 200 57(~ 357 4525 20-Aug-2001 2240 3425 (3 0 500 47C 377 3450 3450 1557 2850 310( 0 0 0 0 690 50~ 0 0 55( 0 200 57C 367 4525 21-Aug-2001 2244 3400 0 0 500 47¢ 380 3450 3450 1556 2850 310~ 0 0 0 0 690 50~ 0 0 55( 0 175 57E 351 4525 22-Aug-2001 1939 3400 0 0 500 47C 309 3450 3450 1389 2850 310~ 0 0 0 0 690 50~ 0 0 55( 0 175 57C 273 4525 23-Aug-2001 2195 3400 0 0 500 47C 322 3450 3450 1560 2850 310( 0 0 0 0 690 50(] 0 0 55¢ 0 175 57E 0 4525 24-Aug-2001 2192 3400 0 0 500 47C 322 3450 3450 1558 2850 310~ 0 0 0 0 690 50~ 0 0 55{~ 0 175 57(] 356 4525 25-Aug-2001 2205 3400 (3 0 500 47£ 324 3450 3450 1562 2850 310( 0 0 0 0 690 50~ 0 0 55C 0 125 58E 383 4525 26-Aug-2001 2181 3400 0 0 500 47(~ 329 3450 3450 1546 2850 310~ 0 0 0 0 690 50(] 0 0 575 0 125 58(3 362 4525 27-Aug-2001 2210 3400 0 0 500 47(~ 351 3450 3450 1556 2850 310~ 0 0 0 0 690 50~ 0 0 55C 0 125 58(] 362 4525 28-Aug-2001 2176 3400 0 0 500 47C 348 3450 3450 1538 2850 310~ 0 0 0 0 690 50~ 0 0 55C 0 125 58(3 363 4525 29-Aug-2001 2189 340~ 0 0 500 47~ 351 3450 3450 1533 2850 310~ 0 0 0 0 690 50(3 0 0 56~ 0 75 582 36~ 4450 30-Aug-2001 2195 3400 0 0 500 53C 351 3450 3450 1533 2850 310(~ 0 0 0 0 710 55(] 0 0 57(~ 0 75 582 349 4450 31-Au~-2001 2133 3400 0 0 550 53C 356 3400 3450 1509 2850 310~ .0 0 ~ 0 710 55(] 0 0 55(] 0 75 585 356 4450 ~uTAL 69,071 0 11,391 47,610 0 0 0 0 10,689 MAXIMUM 3,425 0 550 53(3 3,475 3,475 3,500 3,100 0 0 710 550 0 575 505 585 4,550 AVERAGE 2,228 3,404 0 0 501 494 367 3,450 3,452~ 1,536 2,992 3,100 0 0 0[ 0 673 496 0 0 553 0 273 561 345 4,510 # DAYS 31 0 31 31 0 0 0 0 30 09/12/2001 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC no,tried on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. C24A-23 shut in for field study and evaluation per Doug Marshall. WATER INJECTION REPORT PLATFORM C · July-2001 C23-23 C41-23 (]24-2.3 C"34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 f< i~:~ =:· ACT ACT ACT ACT ACT ACT ACT ACT ACT ~,ii~:~i;,=' INJ INJ ANNU 1NJ INJ ANNU INJ INJ ANNU ' INJ INJ ANNU INJ IN,I ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ 01-$ul--2001 2383 3400 0 0 450 44~ 370 3450 3450 1551 2900 310~ 0 0 0 0 130 50 0 0 550 0 2150 395 360 4500 02-{ul-2001 2383 ~{00 0 0 450 44~ 368 3450 3450 1570 2900 3106 0 0 0 0 130 50 0 0 550 0 2000 416 352 4500 03-$ul-2001 2391 3400 0 0 450 44~ 367 3400 3400 1572 2800 3106 0 0 0 0 130 50 0 0 550 0 1850 425 348 4500 04-{ul-2001 2382 3400 0 0 450 64~ 368 3400 3400 1566 2800 3106 0 0 0 0 130 50 0 0 550 0 1750 43~ 355 4525 05-$u1-2001 2371 3400 0 0 470 47~ 370 34~0 3400 1561 2800 3106 0 0 O 0 430 250 0 0 550 0 1750 48£ 347 4600 06-Jul-2001 2365 3400 0 0 480 47~ 365 3450 3450 1558 2800 3106 0 0 0 0 450 2~ 0 0 575 0 1600 45~ 339 4500 07-{ul-2001 2364 3400 0 0 480 47~ 365 3450 3450 1563 2800 3106 0 0 O 0 450 250 0 0 550 0 1600 455 343 4500 08-{ul-2001 2264 3400 0 0 480 47~ 361 3450 3450 1512 2750 3106 0 0 O 0 470 250 0 0 550 0 1500 46~ 341 4550 09-{ul-2001 2373 3400 O 0 490 475 376 3450 3450 1610 2800 3106 0 0 {] 0 480 306 0 0 550 0 1350 46-' 337 4550 10-{ul-2001 2362 3400 0 0 490 475 373 3450 3450 1602 2850 3106 0 0 O 0 490 306 0 0 550 0 1300 475 376 4550 ! l-Jul-2001 2291 3400 0 0 490 48( 319 3450 3450 1556 2800 3106 0 0 {] 0 495 306 0 0 550 0 1300 47-' 364 4500 12-{ul-2001 2319 3400 0 0 490 48( 343 3450 3450 1568 2800 3106 0 0 {] 0 495 306 0 0 550 0 1150 48-' 365 4500 13-Jul-2001 2347 3400 0 0 490 48( 345 3450 3450 1576 2800 3106 0 0 G 0 ' 495 306 0 0 550 0 !125 49( 340 4500 14-{ul-2001 2339 3400 ~] 0 490 48( 346 3450 3450 1568 2800 3106 0 0 G 0 495 306 0 0 550 0 1075 495 335 4500 15-Jul-2001 2341 3400 O 0 490 48( 348 3450 3450 1570 2800 3106 0 0 G 0 495 306 0 0 550 0 1025 49.' 353 4500 16-Jul-2001 2352 3400 {] 0 490 48( 354 3450 3450 1573 2800 3106 0 0 {] 0 ' 495 306 0 0 550 0 975 50( 338 4500 17-{ul-2001 2369 3400 {] 0 490 48( 362 3450 3450 1581 2800 3106 0 0 G 0 495 30( 0 0 550 0 950 ~ 389 4500 18-{ul-2001 2352 3400 {] 0 490 48( 363 3450 3450 1567 2800 3106 0 0 G 0 495 30( 0 0 550 0 950 ~ 369 4500 19-{ul-2001 2355 3400 ~] 0 490 490 367 3475 3475 1575 2800 3106 0 0 {] 0 495 306 0 0 550 0 900 50( 361 4550 20-~ul-2001 1987 3400 G 0 490490 338 3475 3473 1349 2800 310( 0 0 {] 0 495 30( 0 0 550 0 900 50( 367 4550 21-Jul-2001 2305 3400 {] 0. 490 490 390 3450 3450 1588 2800 310( 0 0 (] 0 495 306 0 0 550 0 810 52.~ 360 4550 22-{ul-2001 2291 3400 ~] 0 490 490 385 3450 34501573 2850 310( 0 0 ~] 0 495 30( 0 0 550 0 760 52( 362 4550 23-Jul-2001 2292 3400 {] 0 490 49( 385 3450 34501569 2850 310( 0 0 {] 0 495 30( 0 0 550 0 740 52( 360 4550 24-Ju1-2001 2297 3400 ~ 0 490 490 386 3450 34501566 2800 310( 0 0 6 0 495 30( 0 0 550 0 740 52( 363 4550 25-{ul-2001 2343 3400 G 0 490 490 392 3450 34501587 2800 310( 0 0 ~ 0 495 30( 0 0 550 0 740 52( 377 4550 26-$u{-2001 2332 3400 C 0 490 490 392 3450 34501576 2850 310( 0 0 6 0 495 30( 0 0 575 0 675 525 365 4500 27-{ul-2001 2322 3400 {] 0 490 490 390 3475 3475 1569 2850 310( 0 0 {]0 495 30( 0 0 550 0 650 53( 367 4475 28-J'ul-2001 2313 3400 ~ 0 490 490 390 3475 34751559 2850 310( 0 0 C 0 495 30( 0 0 550 0 625 53( 372 4500 29-Jul-2001 2318 3400 6 0 490 490 391 3475 34751567 2850310~ 0 0 ~] 0 495 30( 0 0 560 0 575 53-' 369 4500 30-$ul-2001 2124 3400 ~ 0 490 490 372 3500 3506 1466 2800 3100 0 0 ~ 0 495 30( 0 0 570 0 575 53.' 354 4500 ....... 31-Jul-2001 2294 3400 6 0 490. 490 390 3500 35061587 2800 310( 0 0 {] 0 495 30( 0 575 53.~ 375 4500 ¥OYAL 71,921 0 !1,431 48,355 0 0 0 0 11,103 MAXIMUM 3,400 {] 490 490 3,500 3,500 2,900 3,106 0 {] 495 306 0 575 2,150 535 4,600 AVERAGE 2,320 3,400 O 0- 483 477 369 3,452 3,452 1,560 2,816 3,10( 0 0 G 0 441 261 0 0 553 0 1,118 496 358 4,519: #DAYS 31 0 31 31 0 0 0 0 31 08/14/2001 "41-23 shut in due to annular communication problem. 334-23 has developed nn annular communication problem. AOC, CC notified on 12/12/99. Verbal approval to continue to inject received f~om Mr. Wondzell on 12/14/99. 324A-23 shut in for field study and evaluation per Doug Mnrshall. WATER INJECTION REPORT PLATFORM C June-2001 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C'24A- 14 -- & ' 'i=ii~:~'" ACT ACT ACT ACT ACT ACT ACT ACT ACT 01-Jun-2001 345 3475 6 0 425 43( 394 3500 350(3 1923 3400 3400 0 0 ~ 0 70 6~ 0 0 550 251 4550 25 357 4575 02-Jun-200 ! 352 3475 ~ 0 425 43( 395 3500 3500 1943' 3400 3400 0 0 G 0 70 ~ 0 0 550 253 4550 25 358 4575 03-Jun-2001 343 3475 ~ 0 425 43( 395 3500 35013 1941 3400 3400 0 0 G 0 70 0 0 550 249 4550 25 358 4575 04-Jun-2001 340 3500 (~ 0 425 43( 393 3500 35013 1932 3400 3400 0 0 ~ 0 70 ~ 0 0 550 246 4600 3~ 366 4600 05-Jun-2001 333 3500 ~ 0 425 43( 391 3500 35013 1922 3400 3400 0 0 G 0 70 0 0 550 256 4600 3~ 371 4600 06-Jun-2001 886 3500 ~ 0 425 43( 368 3500 3500 1466 3400 3400 0 0 G 0 70 ~ 0 0 575 196 4600 3~ 280 4~00 07-Jun-2001 1596 3400 ~ 0 450 42{ 390 3500 3500 1814 3200 3200 0 0 G 0 125 0 0 550 246 4500 3(~ 378 4500 0g-Jun-2001 1574 3400 ~ 0 420 42( 388 3500 3500 1703 3100 3100 0 0 G 0 110 5( 0 0 55(1 258 4600 3(] 368 4600 09-Jun-2001 1912 3400 ¢ 0 460 42{ 386 3500 35013 .1623 3100 3100 .0 0 G 0 80 5( 0 0 550 262 4600 30 352 4600 10-Jun-2001 2029 3400 ~ 0 460 425 389 3500 3500 1601 3150 3150 0 0 ~ 0 70 5( 0 0 550 262 4550 35 354 44500 1 l-Jun-2001 2363 3400 ~ 0 425 42~ 384 3500 350~ 1588 3100 3100 0 0 {] 0 70 5( 0 0 550 246 4550 35 350 4600 12-Jun-2001 2570 3400 ~ 0 425 43( 385 3500 3500 1590 3125 3125 0 0 13 0 70 5( 0 0 550 253 4550 35 353 4600 13-Jun-2001 2872 3400 £ 0 430 43( 380 3500 3500 156~. 3125 3125 0 0 ~ 0 70 5( 0 0 550 219 4550 35 318 4600 14-Jun-2001 2746 3400 ~ 0 430 43( 376 3500 3500 1572 3125 3125 0 0 G 0 70 5( 0 0 550 236 4550 35 350 4600 15-Jun-2001 270~ 3400 C 0 430 43( 369 3500 350~ 1575 3125 3125 0 0 ~ 0 70 5( 0 0 550 228 4550 35 338 4600 16-Jun-2001 2727 3400 ~ 0 430 43( 367 3500 3500 1586 3125 3125 0 0 G 0 70 5( 0 0 550 211 4550 35 317 4600 17-Jun-2001 2749 3400 £ 0 430 43( 372 3500 350~ 1595 3125 3 ! 25 0 0 (~ 0 70 5( 0 0 550 205 4550 35 346 4600 18-Jun-2001 323 1850 ~ 0 430 43( 44 1400 1400 189 1400 1400 0 0 13 0 70 5( 0 0 550 132 4200 90 304 4275 19-Jun-2001 718 3375 £ 0 430 43( 220 3475 3475 755 3100 3100 0 0 G 0 70 5( 0 0 550 62 3300 . 9~ 122 3300 20-1un-2001 2633 3375 (~ 0 430 43( 0 3475 3475 1586 3100 3100 0 0 13 0 70 5( 0 0 550 61 3300 9(1 122 3300 21-Jun-2001 2569 3375 ( 0 450 44( 380 3450 34513 1585 3100 3100 0 0 13 0 130 5( 0 0 550 72 3450 2313 151 3500 22-Jun-2001 2502 3375 ~ 0 450 44( 372 3450 3450 1562 3100 3100 0 0 13 0 130 5( 0 0 550 100 3400 235 160 3500 23-Jun-2001 245 ! 3375 ~ 0 450 44~ ' 407 3400 3400 155 ! 3100 3100 0 0 13 0, 130 5( 0 0 550 117 3400 2713 ! 55 3500 24-Jun-2001 2476 3400 1~ 0 450 44( 393 3400 3400 1573 3100 3100 0 0 13 0 130 5( 0 0 550 114 3450 260 178 3500 25-Jun-2001 2399 3400 (~ 0 450 44( 386 . 3400 3400 1566 3100 3100 0 0 13 0 130 5( 0 0 550 138 3450 260 181 3500 26-Jun-2001 1972 2900 {~ 0 450 44~ 385 2800 2800 1302 2800 275( 0 0 0 0 130 5( 0 0 575 238 4200 90 381 4250 27-Jun-2001 1789 3250 {~ 0 450 44( 27'7 3300 3300 1142 3000 3000 0 0 0 0 130 5£ 0 0 550 189 4200 80 330 4300 28-~un-2001 2099 3250 G 0 450 44~ 325 3300 3300 1361 2900 2190~ 0 0 0 0 130 5C 0 0 550 0 3050 250 419 4500 29,]un-2001 2439 3400 (~ 0 450 44~ 372 3450 3450 1604 2900 3 0 0 0 0 130 5( 0 0 560 0 2600 338 405 4550 30-Jun-2001 2407 3375 13 0 450 64~ 371 3400 3400 1593 2900 310( 0 0 0 0 130 5¢ 0 0 570 0 2300 375 364 4400 TOTAL 55,222 0 10,454 46,311 0 0 0 5,300 9,186 MAXIMUM 3,500 0 460 44~ 3,500 3,500 3,400 3,40~ 0 0 130 6(] 0 575 4,6O0 375 4,6O0 AVERAGE 1,841 3,334 0 0 438 432 348 3,373 3,373 1,544 3,080 3,092 0 0 0 0 94 52 0 0 553 177 4,062 107 306 4,280 # DAYS 30 0 29 30 0 0 0 27 30 07/10/2001 .~. C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AC}GCC notified on 12/12/99. Verbal approval to continue to inject received from Mr, Wondzell on 12/14/99. .. WATER INJECTION REPORT PLATFORM C May-2001 C23-23 C41~23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 ~' ..... i~ ~ =' :"~ ACT ACT ACT ACT ACT ACT ACT ACT ACT 01-May-2001 1380 3400 0 450 450 377 3450 3450 1836 3350 335~ 0 0 0 0 50 5~ 0 0 550 167 4500 15 370 4975 02-May-2001 930 3400 0 0 450 450 384 3450 3450 1874 3350 335~ 0 0 0 0 50 5£ 0 0 550 142 4500 15 249 4575 03-May-2001 738 3450 0 0 450 450 377 3450 3450 1849 3350 3350 0 0 0 0 50 56 0 0 550 193 4500 15 399 4550 04-May-2001 650 3400 0 ~ 0 450 450 378 3450 3450 1853 3350 335~ 0 0 0 0 50 5~ 0 0 550 221 4550 15 399 4575 05-May-2001 596 3400 0 0 450 450 378 3450 3450 1852 3350 3350 0 0 0 0 50 5~ 0 0 550 161 4550 IS 332 4575 06-May-2001 557 3400 0 0 450 450 375 3450 3450 1843 3350 335~ 0 0 0 0 50 5~ 0 0 575 180 4550 15 368 4575 07-May-2001 534 3400 0 0 450 450 380 3450 34501857 3350 335~ 0 0 0 0 50 56 0 0 550 173 4550 15~371 4575 0g-May-2001 197 3400 0 0 450 450 146 3450 3450 713 3350 335~ 0 0 0 0 50 5~ 0 0 550 190 4550 I 401 4575 09-May-2001 0 2800 25 0 450 450 0 1450 1450 0 1500 150~ 0 0 0 0 50 5~ 0 0 550 115 4300 30 209 4350 10-May-2001 130 2600 50 0 480 44~ 51 1375 1375 197 1475 1475 0 0 0 0 50 56 0 0 550 178 4500 2( 379 4600 1 I-May-2001 704 3400 0 0 485 44~ 410 3400 3400 1977 3475 330~ 0 0 0 0 50 56 0 0 550 160 4500 20 398 4600 12-May-2001 529 3450 0 0 450 435 401 3450 3450 1953 3500 332~ 0 0 0 0 50 56 0 0 550 171 4525 I.' 402 4600 13-May-2001 480 3450 0 0 475 435 399 3450 3450 1937 3500 33.~ 0 0 0 0 50 5~ 0 0 550 170 4500 1.~ 395 4575 14-May-2001 448 3450 0 0 475 435 392 3450 3450 1903 3500 335~ 0 0 0 0 50 5~ 0 0 550 162 4500 15 362 4575 15-May-2001 436 3450 0 0 450 435 402 3450 3450 1966 3500 335~ 0 0 0 0 60 56 0 0 550 170 4500 2~ 404 4600 16-May-2001 298 3400 0 0 435 435 266 3450 3450 1247 3300 330~ 0 0 0 0 60 5£ 0 0 550 92 39002~ 218 4000 17-Mny-2001 416 3400 0 0 435 435 395 3450 3450 1940 3300 330~ 0 0 0 0 60 56 0 · 0 550 128 4500 20 424 4500 18-May-2001 381 3400 0 0 435 435 388 3450 3450 1880 3300 330C 0 0 0 0 60 5C 0 0 550 136 4550 1~ 400 4450 19-May-2001 365 3400 0 0 435 435 383 3450 3450 1835 3300 330~ 0 0 0 0 60 5C 0 0 550 134 4600 Il 377 4600 20-M. ay-2001 356 3400 0 0 435 435 380 3450 3450 1819 3300 330~ 0 0 0 0 60 5C 0 0 550 105 4400 !1 337 4450 21-May-2001 363 3450 O 0 425 43~ 389 3450 3450 1842 3350 335~ 0 0 0 0 70 5£ 0 0 550 218 4525 2~ 363 4575 22-May-2001 367 3400 0 0 435 435 382 3450 3450 1799 3300 330~ 0 0 0 0 60 56 0 0 550 127 4400 !! 368 4450 23-May-2001 556 3400 O 0 435 435 383 3450 3450 1814 3300 330~ .0 0 0 0 60 5C 0 0 550 162 4400 Il 354 4450 24-May-2001 449 3450 0 0 400 425 395 3450 3450 1873 3350 3356 0 0 0 0 70 6~ 0 0 550 174 4425 2.' 352 4500 25-May-2001 401 3450 O 0 400 42~ 391 3450 3450 1854 3350 335~ 0 0 0 0 70 6~ 0 0 550 180 4425 2.~ 353 4500 26-May-2001 383 3450 O 0 425 43~ 391 3450 3450 1857 3350 335C 0 0 0 0 70 6C 0 0 575 176 4450 2~ 369 4500 27-May-2001 373 3450 O 0 425 43~ 389 3450 3450 1843 3350 335C 0 0 0 0 70 6C 0 0 550 194 4500 2.~ 385 4550 28-May-2001 363 3450 G 0 425 43£ 389 3450 3450 1842 3350 335~ 0 0 0 0 70 6~ 0 0 550 218 4525 2.' 363 4575 29-May-2001 364 3450 0 0 425 43~ 393 3450 3450 1857 3350 3356 0 0 0 0 70 6~ 0 0 560 238 4550 25 361 4600 30-May-2001 366 3450 0 0 425 43C 399 3450 3450 1932 3350 335~ 0 0 0 0 70 6C 0 0 570 219 4550 2.' 359 4600 3 l-Ma~-2001 359 3475 0 0 425 43~ 396 3500 3500 1945 3400 340( 0 70 6C 0 0 560 221 4550 2.~ 365 4575 TOTAL 14,469 0 10,959 52,789 0 0 0 5,275 11,186 MAXIMUM 3,475 50 485 450 3,500 3,500 3,500 3,40~ 0 0 70 6~ 0 575 4,600 36 4,600 AVERAGE 467 3,378 2 0 441 438 354 3,319 3,319 !,703 3,244 3,218 0 0 0 0 58 53 0 0 553 170 4,478 2g 361 4,527 · # DAYS 30 0 30 30 0 0 0 31 31 06/13/2001 C41-23 shut in due to annular communication problem. · C34-23 has developed an annular communication problem. AOGCC notif'~! on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. ApriL2001 ACT DATE & NOTES lNJ INJ ANNU 01-Apr-2001 02-Apr-2001 03-Apr-2001 04-Apr-2001 05-Apr-200 1 06-Apr-2001 07-Apr-2001 0g-Apr-2001 10-Apr-2001. 11 -Apr-2001 12-Apr-2001 13-Apr-200 ! 14-Apr-2001 15-Apr-2001 ! 6-Apr-200 ! 17-Apr-2001 ! 8-Apr-200! ! 9-Apr-200 ! 20-Apr-2001 2 ! -Apr-200 ! 22-Apr-2001 23-Apr-2001 24-Apr-200 ! 25-Apr-2001 26-Apr-2001 27-Apr-2001 28-Apr-2001 29-Apr-200 1 30-Apr-2001 TOTAL MAXIMUM AVERAGE # DAYS 05115/2001 C23-23 C41-23 ACT INJ INJ ANNU 0 880 160U 0 500 49( 0 880 160(] 0 500 49( 0 940 160~ 0 500 49( 0 94O 160~ 0 5OO 49( 0 480 160~ 0 500 49( 0 350 160~ 0 5OO 49( 0 290 I85 0 50O 49( 0 29O 185 0 5OO 49( 0 29O 18-q 0 5O0 49( 0 29O 185 0 500 49( 0 290 ! 85 0 500 49( 0 0 0 490 47.~ 0 0 0 49O 47.~ 0 0 0 490 47( 0 0 0 490 470 0 0 0 490 470 0 0 0 49o 470 0 0 0 49O 470 0 0 0 490 470 0 0 0 49O 470 0 0 0 490 470 0 0 0 490 470 0 0 0 49O 470 0 0 0 0 49O 470 0 0 ~ 0 490 470 0 0 0 450 450 0 0 0 450 450 0 0 ~ 0 450 450 0 0 0 0 450 450 172 2800 0 0 450 450 : 0 2,800 1,600 500 490 6 291 351 0 487 474 I 0 172 WATER INJECTION REPORT PLATFORM C C24-23 C23-26 ACT ACT ACT INJ INJ ANNU INJ INJ ANNU 1NJ INJ ANNU 374 3450 3450 392 3450 3450 396 3450 3450 390 3450 3450 388 3450 3450 387 3450 3450 384 345O 3450 385 3450 3450 382 3450 3450 388 3500 34~ 387 3500 345~ 39 ! 3500 345(3 394 3500 345(] 396 3500 345~ 393 3500 345U 395 3500 3475 394 3500 3475 392 3500 3475 390 3500 3475 389 3500 3475 385 3500 3475 383 3500 3475 379 3500 3475 382 3450 345~ 378 3450 345(] 379 3450 345(1 390 3450 345(3 385 3450 345(] 11,618 3,5OO 3,475 387 3,473 3,457 30 1765 3350 335( 1895 3350 335( 1891 3350 335( 1881 3350 335( 1856 3350 335( ! 836 3350 335( 1825 3350 335( 1819 3350 335( 1806 3350 335( 1801 3350 335( ! 786 3300 330( 1808 3500 335( 1808 3500 335( 1833 3500 3375 ! 842 3500 337.' 1847 3500 335( 1844 3500 337.~ 1855 3500 340( 1855 3500 334~ 1842 3500 1832 35O0 ~ 1828 3500 ~00 1810 3500 3400 1800 35OO .~ 1774 3500 792 3350 3350 ! 1770 3350 3350 1768 3350 3350~ 1855 3350 33 1839 3350 335( 54,763 3,500 3,400' 1,825 3,418 3,364: 3O 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 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C~14~ C41-26 C24A-23 C24A- ! 4 ACT ACT ACT ACT I INJ ]]'~'J ANN].J ~J ~J ANNU ~J l~{J A4~NU ]]~J ]~J ANNU 0 0 55~ 0 0 550 0 0 55~ 0 0 550 0 0 55(] 1.01 !1,300 575 0 0 55(] 0 0 55(] 0 0 55C 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55~ 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55C 0 0 55(] 0 0 55(] 0 0 55(] 400 ! ,300 575 0 0 55(] 548 1,375 55(] 790 1,400 560 954 !,375 57C 256 4500 269 4500 259 4550 210 4550 216 4550 224 4550 242 4550 211 4550 203 4550 121 4550 264 4450 245 45O0 237 4550 213 4550 179 4500 185 4500 186 4500 165 4525 157 4525 149 4525 139 4525 133 4525 129 4525 122 4450 126 4450 163 4450 174 4525 162 4500 156 4500 169 4500 3,703 1,400 575 123 225 553 5 5,664 4,550 0 189 4,516 0 30 338 4550 346 4550 370 4600 368 4600 370 4600 373 4600 367 4600 365 4600 380 4600 163 4600 384 4500 379 4550 386 4600 377 46O0 367 4600 374 4600 374 4600 368 4625 370 4625 366 4625 381 4625 392 4625 372 4625 238 3150 408 3150 381 4500 383 4600 381 4575 383 4575 368 4575 10,872 4,625 362 4,494 30 0 760 6O( 0 760 60( 0 770 60( 0 770 60( 0 770 60( 0 770 60( 0 770 60( 0 770 60( · 0 770 60( 0 770 60( 0 770 60( 0 790 622 0 79O 625 0 790 62.' 0 775 625 0 770 622 0 770 62.5 0 770 622 0 770 622 0 770 0 770 622 0 770 622 0 · 770 622 0 770 622 0 770 622 0 775 622 0 775 625 0 775 625 0 775 625 0 775 625 0 790 625 · 0 772 61~ 0 241-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notif'mt on 12/12/99; Verbal approval to continue to inject received from Mr. WoMzell on 12/14/99. C23-23 shut in for repairs from 4/1/01 thru 4/29/01. Retm'ned to injection on 4/30/01 ~ ! :30 p.m. March-2001 [ C23-23 I [NJ ~IJ A~ WATER INJECTION REPORT PLATFORM C C41-23 C24-23 ACT ACT INS INJ ANNU rNJ INJ ANNU OI-Mar-2001 02-Mar-200 I 03-Mar-2001 04-Mar-200 I 05~Mar-2001 06-Mar-2001 07-Mar-2001 08-Mar-200 1 09-Mar-200 I O-Mar-2001 1 -Mar-2001 12-Mar-2001 3-Mar-200 I 4-Mar-2001 5-Mar-2001 6-Mar-200 I 7-Mar-200 I 8-Mar-200 i 9-Mar-200 i 20-Mar-2001 I -Mar-2001 22-Mar-2001' 23-Mar-2001 24-Mar-200 I 25-Mar-2001 26-Mar-200 l 27-Mar-2001 28-Mar-2001 29-Mar-2001 30-Mar-2001 31-Mar-2001 TOTAL MAXIMUM AVERAGE # DAYS 0 1700 160~ 0 1700 160~ 0 1500 150~ 0 1500 150~ 0 1500 150~ 0 1450 145C 0 1450 145~ 0 1700 160~ 0 1500 140~ 0 1500 140~ 0 1450 135C 0 1400 135( 0 1400 135( 0 1400 135( 0 1400 100( 0 580 80( 0 36O 90( 0 295 92.' 0 295 102.~ 0 350 ! 17.~ 0 480 132.' 0 480 132! 0 620 150( 0 700 155( 0 615 155( 0 615 155( 0 615 1554 0 615 155~ 0 880 0 880 160a 0 ! ,700 1,600 0 1,018 1,383 0 0 500 520 0 500 52C 0 500 520 0 500 520 0 500 520 0 500 52~ 0 500 52~ 0 500 52¢ 0 500 52C 0 500 52C 0 500 52( 0 500 52( 0 500 52C 0 500 52( 0 500 52f 0 500 50.~ 0 500 50( 0 500 50.~ 0 500 50( 0 S00 50( 0 500 50( 0 500 50( 0 500 50( 0 500 50( 0 500 50( 0 500 50( 0 500 50( 0 500 50( 0 500 50( 0 500 49( 0 500 49( 500 520 5OO 509 424 350O 350( 412 3500 350( 405 3500 350( 402 3500 350( 403 3500 350( 409 3500 350( 402 3500 350( 424 3500 350( 402 3450 345( 402 3450 345( ,403 3450 345( 405 3450 345( 408 3400 335( 405 3400 335( 397 34O0 345( 401 3500 3450 404 3500 3475 399 3500 345( 394 3500 342: 398 3500 345( 399 3500 345Q 393 3500 3450 391 3500 3450 391 3500 3450 391 3500 3450 391 3500 3450 394 3500 3450 394 3500 3450 392 3500 3450 392 3450 3450 393 3450 3450 12,420 3,500 3,5001 401 3,481 3,456 31 04/1212001 C34-23 ACT INI INJ ANNU 2010 3400 340( 1940 3400 340( 1902 3400 340( 1885 340O 34O{ 1870 3400 340( 1891 3400 340( 1856 3400 340( 2010 3400 340( 1852 3100 335( 1843 3100 335( 1847 3100 335( 1855 3100 335( 1865 3100 3350 1863 3100 3350 1825 3100 3345 1845 3500 335~ 1861 3500 3375 1836 3500 3350 1824 3500 3325 1846 3500 3350 1858 3500 3350 1830 3500 3350 1830 3500 3350 1853 3500 3350 1856 3500 3350 1869 3500 3350 1881 3500 3350 1872 3500 ' 3350 1884 3500 3350 1843 3350 3350 1837 3350 3350 57,939 3,500 3,4001 1,869 3,374 3,363 31 C23-26 C41-26 ACT INJ INJ ANNI 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 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ACT INJ INJ ANNU 0 650 50~ 0 650 500 0 650 50~ 0 650 50~ 0 700 550 0 700 550 0 700 550 0 650 5~ 0 700 55~ 0 700 55C 0 700 55C 0 700 55C 0 700 55~ 0 7O0 55~ 0 740 60~ 0 750 60~ 0 750 60~ 0 750 60( 0 750 60~ 0 750 60( 0 750 60C 0 750 60C 0 750 60( 0 750 60{ 0 750 60~ 0 750 60C 0 750 60C 0 750 60~ 0 750 60( 0 760 60~ 0 760 60~ 760 600 720 569 C44-14RD ACT INJ INJ ANNU C24A-23 ACT INJ INJ ANN1 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550! 0 0 550: 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 55O 0 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550l 0 0 550 0 0 550 0 0 550I 00 0 550 0 550I 0 0 550I 0 ~ 262 4500 258 4500 258 4500 256 4500 242 4500 230 4500 209 4500 262 450O 201 4500 265 4500 248 4500 207 4500 236 4550 286 4550 224 4500 203 4550 198 4450 203 4425 256 4425 274 4400 242 4400 240 4400 272 4400 269 4400 22O 455O 273 4550 271 4550 265 4550 27O 455O 272 4500 265 4500 7,637 4,550 246 4,490 31 C24A-14 INJ rNJ Alq~ 390 4550 387 4550 380 4550 378 4550 382 4550 381 4550 377 4550 390 4550 347 4550 384 4550 389 4550 388 4600 398 4600 386 4600 376 4550 368 4500 361 4525 364 4500 368 4500 368 4500 387 4500 386 4500 380 4500 390 4500 344 4575 412 4575 392 4575 332 4575 389 4575 385 4550 375 4550 0' 11,734 4,600 0! 379 4,545 " 31 C41-23 shut in due to annular communication problem. :- C34-23 has developed an annular communication problem. AOGCC notified on 12112/99. Verbal approval to continue to inject received from Mr. Wondzell on 12114199. C23-23 shut in for upcoming drilling operation in April. February-200 1 ,;-:.:.:.~.:.:.:.:.:.~.:.;.:.:.:.:.:::.;.:.:.:.:. o ! -Feb-200 I 02-Feb-2001 03-Feb-2001 04-Feb-2001 05-Feb-200 I 06-Feb-200 I 07-Feb-2001 08-Feb-2001 09-Feb-2001 I 0-Feb-200 I I l-Feb-2001 ! 2-Feb-200 I 13-Feb-200 I 14-Feb-200.1 ! 5-Feb-2001 16-Feb-2001 17-Feb-200 I 18-Feb-2001 19-Feb-2001 20-Feb-2001 2 l-Feb-2001 22-Feb-2001 23-Feb-200 I 24-Feb-2001 25-Feb-2001 26-Feb-2001 27-Feb-2001 2g-Feb-2001 TOTAL MAXIMUM AVERAGE # DAYS 03112/2001 WATER INJECTION REPORT PLATFORM C C41-23 C23-26 C23-23 C24-23 C34-23 ACT ACT ACT ACT ACT , INJ INJ ANNU INJ . INJ ANNU INJ INJ ANNU INJ INS ANNU 1NJ INJ AN'NU 1762 3250 3250 ! 632 3250 3250 1702 3250 3250 1696 3250 3250 1693 3250 3250 1710 3200 3200 1694 3200 3200 ! 708 3200 3200 1667 3200 3200 1653 3200 3200 1680 3200 3200 1674 3200 3200 1667 3200 3200 1674 3200 3200 1647 3250 3200 1652 3250 3200 1649 325O 32OO 1648 325O 32OO 1654 3250 3200 1644 3250 3200 1445 3250 3200 0 2200 2200 0 2200 2200 0 1900 1825 0 1850 1775 0 1750 1750 0 1750 1650 0 1750 1650 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 525 0 500 525 o . 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 523 0 386 3500 3500 379 3500 3500 393 3500 3500 389 3500 3500 386 3500 3500 386 3450 345(3 384 3450 345(3 385 3450 345{1 382 3450 345(3 375 3450 345{] 379 3450 345(3 382 3450 345{1 380 3450 345~ 381 3450 345(] 372 3450 3425 373 3450 3425 368 3500 345(] 368 3500 345(3 367 3500 345(] 366 3500 345(3 333 - 3500 345(] 237 1500 165(] 77 1500 165~ 425 3450 345{] 406 3450 345{] 406 3450 345{] 425 3500 3500 423 3500 3500 10,313 3,500 3,500 368 3,332 3,332 28 1742 3200 320~ 1665 3200 320~ 1741 3200 320~ 1730 3200 320~ 1727 3200 320~ 1733 3200 320~ ! 7.27 3200 320~ 1745 3200 320~ 1728 3200 3200 1711 ' 3200 320~ ! 729 3200 320~ i 739 3200 3200 1728 3200 320~ 1737 3200 320~ 1707 3200 3175 1714 3200 3175 1706 3500 320C 1704 3500 320~ 1708 3500 320~ 1696 3500 3175 1533 3500 3175 887 1800 1625 291 1800 1625 1949 3050 330~ 1863 3300 330~ 1873 3300 3300 2003 3400 3400 2000 3400 340(] 46,816 3,500 3,400 1,672 3,170 3,109 28 34,951 3,250 3,250 1,248 2,900 2,87.~ 21 o o o o o o 0 o o o 0 0 o o 0 o o o o o o o o o o o o o o o o o o o o o o o o 0 o o o 0 o o 0 o o o o o o o o o o o 0 o o c41-26 C44- ! 4RD C24A-23 ACT ACT ACT r~J ]NJ ANNU l]qJ INJ ANNU INJ INJ ANNL 0 800 650 0 800 650 0 8OO 650 0 800 650 o soo 650 0 800 650 0 goo 650 0 800 650 0 800 650 o soo 65o 0 800 65~ 0 800 650 0 800 650 0 800 65d 0 800 650 0 800 650 0 800 650 0 800 651 0 800 65 0 180 I0( 0 300 10.~ 0 300 10.~ 0 300 10! 0 300 10: 0 300 10.~ 0 300 10.~ 0 300 10! 0 300 10! 0 800 650 0 635 475 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 248 44OO 253 4475 277 4500 272 4500 259 4500 266 4525 262 4525 252 4525 250 4500 246 4500 243 4500 258 4500 256 4500 247 4500 246 4450 253 4450 251 4450 248 4450 247 4500 257 4500 260 4500 162 4500 19 4500 263 4350 283 4400 286 4550 286 4500 268 4500 6,918 4,550 247 4,484 28 C24Ao 14 ACT INJ I~J ANN] 356 4475 357 4525 399 4575 392 4575 387 4575 382 4575 370 4575 369 4575 366 4550 369 455O 364 4550 359 4550 355 4550 362 4550 359 4500 359 4500 356 4500 360 4500 362 450O 365 450O 368 45OO 225 3000 32 3000 423 4350 426 4350 421 4550 401 4550 396 4550 10,040 4,575 359 4,414 28 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. C23-23 shut in for upcoming drilling operation at the end of March. All injectors have reduced inected barrels on 2/22 & 2/23 to change accumulator relief valve. RECEIVED fiR 1 3 001 Alaska Oil & Gas Cons. Commission Anchorage WATER INJECTION REPORT PLATFORM C January-2001 C23-23 - C41-23 C24-23' C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 __ 01-Jan-2001 1732 3250 325( 0 500 52~ 371 3400 ~ 1618 2950 3150 ' 0 0 ( 0 780 62~ 0 0 550 141 3400 C 212 3500 02-Jan-2001 1749 3250 325( 0 500 52(] 370 3400 3400 1616 2950 3150 0 0 (~ 0 780 625 0 0 550 132 3400 C 243 3500 03-Jan-2001 1775 3250 3250 0 500 520 373 3400 ~ 1630 2950 3150 0 00 0 780 625 0 0 550 .135 3400 C 257 3500 04-Jan-2001 1822 3300 3250 0 500 52(~ 389 3500 3500 1678 3200 320~ 0 0 05-Jan-2001 1748 3300 3250 0 500 52~ 377 350~ 3500 1609 3000 320~ 0 0 0 0 780 625 0 0 550 120 3500 10~ 260 3500 06-Jan-2001 1726 3250 3250 0 500 52~ 371 3400 34001623 2950 315~ 0 0 0 0. 780 62~ 0 0 550 144 3350 ( 287 3500 07-Jan-2001 1758 3300 3250 0 500 52~ 380 3450 3450 1634 2950 320~ 0 0 0 0 780 625 0 0 550 252 4100 IIX 374 4100 08-Jan-2001 1792 3250 3250 0 500 525 386 3450 3450 1654 3200 320~ 0 0 0 0 785 65C 0 0 550 294 4250 09-lan-2001 1783 3250 3250 0 500 525 384 3450 3450 1642 3200 320~ 0 0 0 0. 785 10-Jan-2001 1773 3300 3250 0 500 52~ 387 3450 3450 1640 2950 320~ 0 0 0 0 785 65£ 0 0 550 272 4350 C 409 4350 1 l-Jan-2001 1750 3~00 3250 0 500 52~ 379 3450 3450 1621 2950 320C 0 0 0 0 785 65C 0 0 550 269 4350 12-Jan-2001 1748 3300 3250 0 500 52~ 376 3450 3450 1610 2950 32IX 0 0 0 0 785 65C 0 0 550 260 4350 C 414 4350 13-lan-2001 1760 3250 3250 0 500 52.~ 378 3450 3450 1621 3200 320C 0 0 0 0 785 65C 0 0 550 264 4450 14-Jan-2001 1752 3250 3250 0 500 52~ 380 3450 3450 1616 3200 320~ 0 0 0 0 785 65C 0 0 550 283 4450 0 402 4400 15-Jan-2001 1760 3250 3250 0 500 52~ 382 3450 3450 1627 3200 32IX 0 0 0 0 785 65£ 0 0 550 271 4450 0~ 398 , 4400 16-Jan-2001 1773 3250 3250 0 500 52~ 382 3450 34501631 3200 32IX 0 0 0 0 785 17-Jan-2001 1730 3250 3225 0 500 52C 371 3425 3425 1589 3200 32IX 0 0 0 0 790 65C 0 0 550 234 4525 C403 4575 18-Jan-2001 1737 3225 3225 0 500 52( 371 3400 3450 1593 3200 32IX 0 0 0 0 650 19-$an-2001 1653 3250 3225 0 500 52~ 371 3450 3450 1529 3200 320~ 0 0 0 0 790 65C 0 0 550 248 4400 ~ 346 4450 20-Jan-2001 1781 3250 3250 0 500 52.~ 393 3450 3450 1657 3200 320C 0 0 0 0 790 65C 0 0 550 288 4500 C 397 4550 2 l-Jan-2001 1562 3250 3250 0 500 52~ 355 3450 3450 1454 3200 32IX 0 0 0 0 790 65¢ 0 0 550 228 4500 C 317 4550 22-Jan-2001 1709 3250 3250 0 500 52~ 375 3450 3450 1610 3200 32IX 0 0 0 0 790 65C 0 0 550 279 4500 C 380 4550 23-Jan-2001 i730 3250 3250 0 500 52~ 378 3450 3450 1625 3200 32~ 0 0 0 0 790 65£ 0 0 550 285 4500 C 395 4550 24-Jan-2001 1732 3250 3250 0 500 52~ 377 3450 3450 1626 3200 32IX 0 0 0 0 790 65C 0 0 550 230 4450 ¢ 369 4500 25-Jan-2001 1738 3250 3250 0 500 52.~ 376 3450 3450 1628 3200 32IX 0 0 0 0 790 65£ 0 0 550 233 4450 ¢ 371 4500 26-Jan-2001 1748 3250 3250 0 500 52-~ 377 3450 3450 1632 3200 32IX 0 0 0 0 790 65¢ 0 0 550 273 4450 C374 4500 27-Jan-2001 1707 3250 3250 0 500 52.~ 376 3450 3450 1600 3200 320~ 0 0 0 0 790 65~ 0 0 550 217 4450 ¢ 348 4500 2g-Jon-2001 175g 3250 3250 0 500 52~ 390 3450 3450 1706 3200 320~ 0 0 0 0 790 65C 0 0 550 269 4450 29-Jan-2001 1741 3250 3250 0 500 525 382 3450 3450 1729 3200 320~ 0 0 0 0 790 65~ 0 0 550 253 4450 ~ 379 4500 30-Jan-2001 1752 3250 3250 0 500 52.~ 387 3450 3450 1735 3200 32IX 0 0 0 0 790 65¢ 0 0 550 257 4450 ~ 379 4500 31-Jan-2001 1752 3250 3250 0 500 52~ 381 3450 3450 1725 3200 32IX 0 0 0 0 790 65~ 0 0 550 262 4450 TOTAL 54,031 0 11,725 50,508 0 0 0 7,264 11,175 MAXIMUM 3,300 3,250 500 525 3,500 3,500 3,200 3,200 0 0 790 790 0 550 4,550 110 4,600 AVERAGE 1,743 3,259 3,248 0 500 524 378 3,444 3,446 1,629 3,129 3,194 0 0 0 0 782 650 0 0 550 234 4,231 10 360 4,267 ~ DA,Y$ ' 31 0 31 31 0 0 0 31 02/12/2001 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGC~ notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. C~0 . tt,,~.~,~ ,~ WATER INJECTION REPORT PLATFORM C December-2000 C23-23 C41-23 C24-23 C34-23 C23-26 ca 1-26 C44-14RD C24 A-23 C24A- 14 __ 0 l-Dec-2000 1872 2550 3200 0 500 54( 389 3400 34251862 3050 327.~ 0 0 0 0 770 65( 0 0 550 147 3400 0 291 3450 0 02-Dec-2000 1716 2550 320~ 0 500 54( 352 3400 3425 1681 3050 327.~ 0 0 0 0 770 65C 0 0 550 123 3400 0 259 3450 0 03-Dec-2000 0 2550 320(] 0 500 54( 0 3400 3425 0 3050 327.~ 0 0 O 0 770 650 0 0 55(]0 3400 0 0 3450 0 04-Dec-2000 ! 84 2550 3200 0 500 54( 76 3400 3425 202 3050 327.~ 0 0 0 0 770 65C 0 0 550 56 3400 O 79 3450 0 05-Dec-2000 1853 2550 320C 0 500 54( 412 3400 3425 1848 3050 327.~ 0 0 0 0 770 65¢ 0 0 550 182 3400 0 366 3450 0 06-Dec-2000 1961 2550 320~ 0 500 54( 410 3400 3425 1947 3050 327_~ 0 0 0 0 770 65{ 0 0 550 180 3400 .0 313 3450 0 07-Dec-2000 1739 3250 325~ 0 500 52£ 406 3500 350C 1825 3300 330( 0 0 0 0 775 62~ 0 0 550 171 3500 0 299 .3500 0 O8-Dec-2000 46~ 2500 2500 0 500 52(. 409 3500 3500 1762 3300 330( 0 0 0 0 775 55[ 0 0 550 141 3500 0 28'/ 3500 0 09-Dec-2000 166 2500 250~ 0 500 52(. 404 3500 3500 1728 3500 325[ 0 0 0 0 770 55[ 0 0 550 131 3500 0 276 3500 0 10-Dec-2000 2048 3250 320~ 0 500 52(. 402 3500 350~ 1729 3500 325[ 0 0 0 0 770 62Z 0 0 550 120 3500 0 279 3500 0 1 l-Dec-2000 1899 3250 325(3 0 500 52(. 404 3500 3500 1740 3500 325( 0 0 0 0 770 62.~ 0 0 550 154 3500 ~ 273 3500 12-Dec-2000 1867 3250 32513 0 500 52[ 404 3500 3500 1751 3500 325[ 0 0 0 0 770 62' 0 0 550 162 3500 0 271 3500 0 13-Dec-2000 1839 3250 325C 0 500 52(. 403 3500 350C 1738 3500 325[ 0 0 0 0 770 62.~ 0 0 550 152 3500 0 268 3500 0 14-Dec-2000 1817 3250 325C 0 500 52( 398 3500 350~ 1726 3500 325(. 0 0 0 0 770 62~ 0 0 550 145 3500 I 257. 3500 15-Dec-2000 1809 3250 325(] 0 500 52( 401 3500 350~ 1726 3500 325(. 0 0 0 0 770 62.~ 0 0 550 138 3500 270 3500 16-Dec-2000 1815 3250 325(] 0 500 52( 402 3500 3500 1730 3500 325( 0 0 0 0 770 - 62.' 0 0 550 132 3500 0! 275 3500 17-Dec-20(X) 1820 3250 325C 0 500 52( 404 3500 3500 1734 3500 325( 0 0 0 0 770 62.' 0 0 550 110 3500 0 275 3500 18-Dec-2000 1838 3250 325C 0 500 52( 406 3500 3500 1746 3500 325( 0 0 0 0 770 62.~ 0 0 550 123 3500 ~ 289 3500 19-Dec-2000 1834 3250 325C 0 500 52( 407 3500 350(3 1740 3500 325C 0 - 0 0 0 770 62.~ 0 0 550 237 4100 389 4100 ( 20-Dec-2000 1723 3250 325C 0 500. 52( 375 3400 340~ 1611 2950 315( 0 0 13 0 780 62.~ 0 0 550 227 4250 0! 395 4350 ( 21-Dec-2000 1793 3250 325C 0 500 52( 398 3500 3500 1724 3500 320( 0 0 0 0 780 62.~ 0 0 550 287 4250 (. 443 4250 C 22-Dec-2000 1787 3250 325C 0 500 52( 398 3500 350C1711 3200 320( 0 0 0 0 780 62.~ 0 0 550 263 4250 ( 434 4300 ( 23-Dec-2000 1778 3000 325C 0 500 52( 393 3450 3450 1698 3300 320( 0 0 0 0 780 62.~ 0 0 550 259 4325 (. 450 4350 ( 24-Dec-2000 1775 3300 325C 0 500 52( 392 3450 3450 1689 3450 320( 0 0 0 0 780 62.~ 0 0 550 268 4350 ( 432 4400 25-Dec-2000 1774 3300 325(] 0 500 52(. 395 3450 3450 1681 3000 320( 0 0 0 0 780 622 0 0 550 247 4400 C 433 4450 C 26-Dec-2000 1444 3300 325C 0 500 52( 321 3450 3450 1363 2950 320( 0 0 0 0 780 62~ 0 0 550 267 4400 C 423 4450 27-Dec-2000 1723 3250 325C 0 500 52( 375 3400 3400 1611 2950 315C 0 0 0 0 780 62.~ 0 0 550 227 4250 C 395 4350 C 28-Dec-2000 1733 5250 325C 0 500 52C 371 3400 3400 1635 2950 315C 0 0 0 0 780 62~ 0 0 550 201 3350 C 317 2700 C 29-Dec-2000 1680 3250 325(] 0 500 52( 365 3400 34001587 2950 315C 0 0 0 0 780 62-~ 0 0 550 223 4250 C 363 4350 C 30-Dec-2000 1726 3250 325(] 0 500 52(. 371 3400 3400 1623 2950 315C 0 0 0 0 780 622 0 0 550 144 3350 C 287 3500 C 3 l-Dec-2000 1720 3250 325C 0 500 52C 369 3400 3400 1614 2950 315C 0 0 0 0 780 622 0 0 550 198 3400 C '310 3500 TOTAL 49,201 0 11,412 49,762 0 0 0 5,415 9,698 MAXIMUM 3,300 3,250 500 5413 3,500 3,500 3,500 3,300 0 0 780 650 ' 0 550 4,400 0 4,450 0 AVERAGE 1,587 3,063 3,190 0 500 524 368 3,455 3,460 1,605 3,242 3,229 0 0 0 0 774 625 . 0 0 550 175 3,720 0 313 3,734 0 # DAYS 30 0 30 30 0 0 0 30 30 01/12/2001 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. WATER INJECTION REPORT PLATFORM C 0t O2-Nov- 03- NOV. 2Lv0-~3 04-Nov-2000 05-.Nov-2Ca30 (~5-Nov- 2~:~'.~0 07. Nov - 2.'.;'00 C,'q-N ov-2CnX~ 1C--No','- I t .Nov-2000 12-Nov-2000 I ! 4-Nov- 15-Nov-2000 16-Nov-2000 ! 7-Nov..2(K)0 18-No',;- 2(;'C~ 19- Nov. 2000 20-Nov-2000 21 ..No~:.2t.~:~.) 22-Nov 26-Nov- 27.Nov.2000 28-N ov-2{'~0 29 -Nov..2{.'.n':~) 30-Nov- TOTAL MAXIMUM AVERAGE . # DAYS 1807 3300 330( 1788 3300 330( 1815 3300 330( 1799 3300 330( 1795 3300 330( 1804 3300 330( 1806 3300 330( 1780 3300 330( 1808 3300 330( 1800 3300 330( 1726 3300 330( 1698 3250 325( 1695 3250 325( 1718 3250 325( 1705 3250 325~ 1687 3250 3250 1702 ' 3250 3250 1710 3250 3250 1694 3250 325~ 1707 3250 3250 1690 3250 325{ 1693 3250 325( 1688 3250 325( 1693 3250 325( 1694 3250 325( 1711 3250 325( 1695 3250 325( 1301 3250 325~ 1704 3250 325~ 1767 3300 3300 51,68o 3,300 3,300i 1,723 3,270 3,270 30 12/1 !/2000 C4 ! ~23 C24-23 C34-23 C23-26 C4 ! -26 C44-14RD C24A-23 ACT ACT ACT ACT ACT ACT ACT 1NJ 1NJ ANNU INJ INJ A4~NU ~NJ ~J ANNU INJ fNJ ANNU i~IJ l~J ANNU tNJ INJ ANNU INJ INJ ANNU 0 500 520 0 500 520 0 500 520 0 500 52O 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 52~ 0 500 52~ 0 500 52~ 0 500 52~ 0 50O 52~ 0 500 52C 0 500 52~ 0 500 53~ 0 500 53~ 0 500 53~ 0 500 52~ 0 500 52~ 0 500 52~ 0 500 520 0 500 535 0 500 52~ O' 500 535 0 500 522 0 435 3500 350( 430 3500 350( 436 3500 350( 43 ! 3500 350( 428 3500 350( 430 3500 350( 432 35OO 350( 422 3500 350( 433 3500 350( 431 3500 350( 426 3500 350( 424 3500 350( 423 3500 350( 431 3500 350( 427 3500 350( 420 35OO 350( 425 3500 350( 426 3500 350( 422 3500 350( 426 3500 350( 420 3500 350( 420 3500 350( 418 3500 35O( 421 3500 350( 419 3500 350( 424 3500 350( 420 3500 350( 321 3500 350( 404 3450 3462,.~ 422 3500 35O( · 12,647 3,500 3,500 422 3,498 3,499 30 1730 3300 330(] 1710 3300 330~ 1736 3300 330~ 1714 3300 330~ 1710 ' 3300 330~ 1720 3300 330~ 1727 3300 330~ 1690 3300 330~ 1733 3300 330( 1723 3300 330~ 1673 3300 330~ 1648 3250 325¢ 1643 3250 325C 1668 . 3250 325C 1657 3250 325C 1639 3250 325¢ 1663 3250 325C 1674 3250 325£ 1662 3250 325C 1684 3250 325C 1667 3250 325C 1669 3250 '325~ 1667 3500 325¢ 1676 3550 325C 1684 3500 325~ 1708 3500 325~ 1693 3500 325C 1297 3500 325~ 1769 3275 325~ 1683 3300 330~ 50,317 3,550 3,300 1~77 3,323 3,270 30 0 0 o o 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 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 0 0 0 0 0 0 0 0 0 0 0 0 760 6012 0 760 6012 0 760 60~ 0 760 60( 0 760 6012 0 760 60{2 0 760 6012 0 760 60( 0 760 60( 0 760 60( 0 760 6012 0 770 60( 0 770 6O{ 0 770 60( 0 770 622 0 770 622 0 770 622 0 770 622 0 770 625 0 770 625 0 770 622 0 770 625 0 770 622 0 770 62~ 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 760 6012 0 0 770 625 0 0 766 613 0 0 0 550 o o 55o 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 55O 0 0 550 0 0 55O 0 0 '550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 108 3500 165 104 3500 165 I!2 3500 165 116 3500 165 120 3500 165 117 3500 165 118 3500 165 121 3500 165 129 3500 165 126 3500 145 120 3500 145 120 3500 160 127 3500 150 !16 3500 150 121 3500 155 126 3500 155 135 3500 155 123 3500 155 129 3500 145 137 3500 145 135 3500 145 136 3500 142 132 3450 142 137 3450 140 130 3500 135 135 3500 135 131 3500 135 104 3500 135 151 3500 150 103 3500 175 3,719 3,500 175 124 3~97 153 30 C4 i-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. RECEIVED DEC 2, 1 000 Alaska Oil 8, Gas Cons. Commission Anchorage WATER INJECTION REPORT PLATFORM C (?~lol~ e.-r - ~ (-~'-~ C23 -23 C4 i -23 (24-23 C34-23 (23 -26 C41-26 C44-14RD (24A-23 C24A- 14 OI-(~l-2~ 1879 3350 33~ 0 5~ 51~ 422 ]450 3450 1824 3350 33~ 0 0 0 750 ~ 0 0 55~ 80 3450 225 3~ 3450 02-C~t-2~ . l~l 3350 33~ 0 5~ 51~ 420 3450 345(]813 35~ 33~ 0 0 0 750 6~ 0 0 55~ 74 3450 22~ 341 35~ 03 -('~1-2~_~ 1886 3450 33~ 0 5~ 51( 426 3450 345{ 1839 35~ 33~ 0 0 0 750 ~ 0 0 550 71 3450 21C 341 3500 ~-~-2~ 1852 3450 33~ 0 5~ 51{ 416 3450 345{ !~8 35~ 33~0 0 0 750 ~ 0 0 550 61 3450 21C 337 05-('~t-2~ 18~ 3450 33~ 0 5~ 51{ 419 3450 3450 1812 35~ 33~ 0 0 0 750 ~ 0 0 550 77 3450 21C 343 35~ ~ -2~ 1658 3350 32~ 0 5~ 51{ 411 3450 345{ 1812 3350 33~ ' 0 0 0 745 ~ 0 0 55~' 86 3450 23( 32~ 35~ 07-~1-2~.~ 1830 3450 33~ 0 5~ 51( ~ 3450 345( 1~! 35~ 33~0 0 0 750 ~ 0 0 550 68 3450 21C 308 35~ 08-~1-2~ 1837 3450 ' 33~ 0 5~ 51{ 410 3450 345( 1~ 35~ 33~ 0 0 0 750 ~ 0 0 55067 3450 21C3~ 35~ ~-('~-2~.~ 1854 3450 33~ 0 5~ 51( 414 3450 345( 1785 35~ 33~ 0 0 ( 0 750 ~ 0 0 550 80 3450 21C 312 35~ ~O-C~-2~ 183~ 3450 33~ 0 5~ 51{ 411 3450 345{ 1767 35~ 33~ 0 0 0 750 6~ 0 0 55g ~ 3450 21C 316 35~ 11-(~1-3~.~ 1~ 3450 33~ 0 5~ 51{ 413 3450 345( 1~5 35~ 33~ 0 0 0 750 ~ 0 0 550 I~ 3450 21C 318 35~ 12-C~-2~ 1871 3350 33~ 0 5~ . 512 418 ~50 345( 18~ 35~ 33~ 0 0 0 750 ~ 0 0 550 83 3450 18~ 312 13-('~i-2~.~ 18~ 3350 33~ 0 5~ ' 512 427 3450 345( 1835 35~ 33~ 0 0 0 750 ~ 0 0 550 73 3450 185 311 35~ ~4-(~-2~) 1870 ~350 33~ 0 5~ 51~ 4~ 3450 345{ 1817 35~ 33~ 0 0 0 750 ~ 0 O 55~ 78 3450 185 307 35~ 1 ~ -('~t-3r~.~O 1881 3350 33~ 0 5~ 51( 424 3450 345{ 1824 35~ 3~0 0 0 750 ~ 0 0 550 74 3450 18C 3~ 35~ I~-C~t-2~) 1791 3350 33~ 0 5~ 51( 4~ 3450 345( 1730 ~5~ ~3~ 0 0 0 750 ~ 0 0 550 72 3450 18C 3~ 35~ ! T-Oc{-3(~.~O 1783 33~ 32~ 0 5~ 512 427 3450 345( 1717 35~ 325( 0 0 0 750 ~ 0 0 550 70 3450 18~ 308 35~ ~8-C)ct-2~)0 1~2 33~ 32~ 0 5~ 512 424 3450 345( 1705 35~ 3~( 0 0 0 750 6~ 0 0 55~70 3450 18{3~ 35~ 19-Oc1-~.~ 1783 33~ 32~ 0 5~ 512 426 3450 345( 1713 35~ 3~( 0 0 0 750 6~ 0 0 550 70 3450 188 271 35~ 20-C~-2~{ 17~ 33~ 32~ 0 5~ 512 4~ 3450 345( 1717 35~ 3~( 0 0 0 750 ~ 0 0 550 68 3450 18~ 345 35~ 2 i-('~t-3(~ 1766 33~ 32~ 0 5~ 512 422 3450 345( 1694 35~ 325( 0 0 0 750 6~ 0 0 550 74 3450 18~ 302 22-0c~-2~ 1747 ~3~ 32~ 0 5~ 512 416 3450 345( !~9 35~ ~25( 0 0 0 0 750 6~ 0 0 55~ 103 3450 18~ 298 35~ 23-(')ct-3rA~ 1788 33~ 32~ 0 ' 5~ 51~ 426 3450 345{ 1708 35~ 3~( 0 0 ~ 0 750 6~ 0 0 550 86 3450 18~ 25~ 35~ 24-C~t-2~ 1782 33~ 32~ 0 5~ 512 428 3450 3450 17~ 35~ 325{ 0 0~ 0 750 6~ 0 0 550 ~ 3450 18~ 197 2~-('~i-3~ 1802 33~ 33~ 0 5~ 52{ 432 35~ 35~ 1723 33~ 33~ 0 0 ~ 0 760 6~ 0 0 550 !17 35~ 18~ 256 34~ 2~-Oct-2G~) 1780 33~ 33~ 0 5~ 52( 426 35~ 35~ 1703 35~ 33~ 0 0 0 0 760 6~ 0 0 5501~ 35~ 19( 284 35~ 27-Oct-2~.~ 1785 33~ 3275 0 ~ 52( 426 3450 345( 17~ 33~ 33~ 0 0 ~ 0 760 6~ 0 0 550 1~ 3450 I~ 281 35~ 28-C)c~-2~X} 1796 33~ 33~ 0 ' 5~ 52{ 430 35~ 3~ 1712 33~ 33~0 0 Q 0 760 6~ 0 0 550 107 35~ 18~ 278 35~ ~9-Ocl-2~ 18~ 33~ 33~ 0 5~ 52( ~ 35~ 35~ 1~7 33~ 33~ 0 0~ 0 7~ 6~ 0 0 55~ 105 35~ 18~ 294 35~ 30-~t-2~ 1767 3300 33~ 0 5~ 52( 422 35~ 35~ 1683 33~ 33~ 0 0 0 0 760 ~ 0 0 55~ 103 35~ 17~280 35~ 3 ~ -('~t-2(~.~ 1782 33~ 32~ 0 ' 5~ 51~ 428 3450 345( 17~ 35~ 3~( 0 0 ~ 0 750 6~ ~ 3450 18~ 197 35~ TOT~ 56,3~ 0 13,~4 54,411 0 [ 0 0 2,608 9,296 M~I~ 3,450 3,3~ 5~ 520 3,5~ 3,5~ 3,5~ 3,3~ 0 0 760 ~ 0 55~ 3,5~ 230 3,5~ A~GE l,g16 3,352 3,2670 5~ 514 422 3,458 3,458 1,755 3,458 3,285 ' 0 0 0 0 752 6~ 0 0 55~ 84 3,458 1963~ 3~495 ~ DAYS 31 0 31 31 0 0 0 31 31 I I/!~2~ C41-23 shut ~ due m a~ular ~ca~on p~l~ ~23 has d~elo~ an a~ular ~fion pmbl~ A~CC ~fifi~ on 1 ~1 ~99. V~al ~m~l m mn~ m ~j~ ~ ~ Mt. W o~H on 1 ~i~. . . . . . WATER INJECTION REPORT PLATFORM C & · , , C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-I4RD C24A-23 C24A-14 ACiF A~'T ACT ACT ~,,CT ACT ACT ACT AC']' ~J tus ~'uu ~1 ~J A~u ~J . .q~ A~U uaJ ~J A~mJ ~J ~J A~U ~' ~ A~U ~J UaJ A~,U ~J ~J ~ Ua~ ~J A~U 1916 3350 335( 0 500 502 449 3500 350( 2149 3400 340( 0 15 O 0 702 56( 0 0 550 126 3500 255 358 3500 1905 3350 335~ 0 SOO 502 446 3500 350( 2131 3400 340( 0 15 0 0 702 56( 0 0 550 130 3500 255 347 3500 C 1931 3350 3350 O 500 50'2 442 3500 350( 2146 3400 340( 0 15 (] 0 702 56( 0 O 550 123 3500 19t2 350 3500 C 2026 3350 335( 0 500 502 445 3500 350( 2151 3400 340( 0 15 0 0 702 56( 0 0 550 128 3500 20(] 329 3500 C 2018 3350 3400 0 500 581] 446 3500 350( 2151 3400 345( 0 15 C 0 702 55C 0 0 550 124 3500 20~ 335 3500 C 2000 3350 340( 0 500 510 443 3500 350( 2135 3400 345( 0 15 0 0 702 55( 0 0 550 123 3500 25C 329 3500 1975 3350 340d 0 soo si~ 43v 3soo 350( 2104 34oo 345c 0 15 ~ 0 7o2 55c 0 0 sso 135 35oo 2sc 322 3soo c 1982 3350 3400 0 500 510 438 3500 350( 2106 3400 345C 0 15 0 0 702 55(: 0 0 S50 135 3500 265 322 3800 1957 3350 340( 0 500 51C 432 3500 350( 2078 3400 345( 0 15 (l 0 702 55( 0 0 550 128 3500 26C 321 3500 C 1969 3350 3400 0 500 51(} 435 ~,500 350( 2085 3400 345( 0 15 O 0 702 55( 0 0 550 130 3500 26C 325 3500 1986 3380 3400 0 soo 81~ 483 3800 380( 2073 34oo 348~ 0 15 u . 0 702 ss~ 0 0 sso 129 3soo 26c ,~ 3soo c 1987 3350 3400 0 500 51~ 438 3500 350( 2108 3400 345C 0 15 0 0 702 SSC 0 0 550 13g 3500 26C 323 3500 38 3350 3400 0 SOO 51{] 11 3500 350( 37 3400 ~45( 0 15 (] 0 702 55( 0 0 550 23 3500 2~] 20 3500 1173 3250 3250 0 500 5I{1 301 3500 350( 1048 3300 330( 0 15 0 0 702' 55( 0 0 550 125 3500 26(: 343 3400 C 1965 3300 3300 0 Soo SiC ' 488 3500 350( 1944 3300 330( 0 15 C 0 702 55( 0 0 550 145 3500 26U 405 3500 1909 3300 33000 500 51~ 475 3500 350( 1938 3300 330 0 15 O0 702 ' 55£ 0 0 550 159 3500 26~363 3500 1900 3350 3300 0 500 51~ 475 3500 350( 1941 3300 33~ 0 15 C 0 720 57~ 0 0 550 145 3500 265 356 3500 C 243 3350 3300 0 500 51C 62 3500 350( 248 3300 332.~ 0 15 00 720 57.~ 0 0 550 20 3500 265 47 3500 2079 3350 3300 0 500 51{~481 3500 350( 2008 · 3300 330( 0 15 (~ 0 720 57.~ 0 0 550 164 3500 25~441 3500 C 1949 3350 33000 500 51C 460 3500 350( 1982 3300 330( 0 15 a0 720 57~ 0 0 550 140 3500 25g370 3500 C 1930 3375 3325 0 500 51i~ 458 3500 350( 1973 3325 332.~ 0 0 ~ 0 720 57.~ 0 0 550 143 3500 255 356 3500 C 1919 3375 3325 0 500 51C 458 3500 350( 1972 3325 33~ 0 0 ~ 0 720 57.~ 0 0 550 141 3500 255 352 3500 C 1920 3375 3325 0 500 51{~ 458 3500 350( 1970 3325 332.~ 0 0 {~ 0 720 57.~ 0 0 550 144 3500 255 345 3500 C 1895 3375 3325 0 500 51g 453 3500 350( 1947 3325 332.~ 0 0 0 0 720 57.~ 0 0 550 135 3500 255 34'/ 3500 1895 3375 3325 0 500 51g 452 3500 350( 1943 3325 332.~ 0 0 C 0 720 57.~ 0 0 550 127 3500 255 345 3500 C 1900 3375 3325 0 500 51~ 455 3500 350( 1948 3325 332.~ 0 0 C 0 720 57.~ 0 0 550 128 3500 255 346 3500 C 1897 3375 3325 0 500 51~ 454 3500 350( 1942 3325 332~ 0 0 ~0 720 57.~ 0 0 550 125 3500 255350 3500 C 1898 3350 3350 0 500 51C 454 3500 350( 1940 . 3350 335( 0 0 0 0 720 575 0 0 550 133 3500 255 342 3500 C 1886 3350 3350 0 500 51~ 450 3500 350( 1925 3350 335( 0 0 C 0 720 57.~ 0 0 550 135 3500 255 330 3500 C 1891 3350 3350 0 500 51C ' 451 3500 ~50( 1935 3350 335( 0 0 0 0 720 575 0 0 550 141 3500 255 328 3500 C 1872 3350 3350 0 500 51C 445 3500 350( 1916 3350 335( 0 0 (~ 0 720 57.~ ' 0 0 550 143 3500 27C 324 3500 55,781 0 13,025 57,974 0 0 0 3,966 10,094 3,375 3,400 500 510 3,500 3,500 3,400 3,450 15 0 720 575 0 550 3,500 270 3,500 0 1,799 3,349 3~46 0 500 509 420 3,500 3,500 1,870 3~354 . 3,370 0 !0 0 0 711 563 0 0 550 128 3,500 252 326 3,497 0 31 0 31 31 .0 0 0 31 · 31 09/18/2000 ~gust 13th - Wells temporarily offiinc duc to repairs to watefllond turbine. [!-23 shut in due to annular communication problem ,4-23 has dcvclopcd an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to contint~ to inj~t received fi'om Mr. Wondzeli on 12/14199. WATER INJECTION REPORT PLATFORM C July- "f.~'~0 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14P, D C24A-23 C24A- 14 01 .Jul~~0-,~O 192 3400 340( 0 550 490 88 3500 350( 259 3400 340( 0 0 0 0 '700 55(1 0 0 550 ' 60 3500 140 166 3500 02-J~tl-2Cn)O 1665 3400 340( 0 550 490 465 3500 350( 2288 3400 340( 0 0 0 0 700 550 0 0 550 183 3500 140 664 3500 03-Jul -2tk~.~ 2063 3400 340( 0 550 490 454 3500 350( 2366 3400 340( 0 0 0 O 700 550 O 0 550 126 3500 140 558 3500 04-$ul-2000 2124 3400 340( 0 550 490 452 3500 350( 2.368 3400 340( 0 0 0 0 700 550 0 0 550 112 3500 175 531 3500 05-Jitl-~O-90 2066 3400 340( 0 550 490 ' 446 3500 350( 2337 3400 340( 0 0 0 0 700 550 0 0 550 108 3500 175 508 3500 ~ ~6-~ htl-2C~. 2073 3400 330( 0 550 485 456 3500 350( 2369 3400 340( 0 0 0 0 700 55{1 0 0 550 107 3500 180 509 3500 07-Jul--2~ 2047 3400 330( 0 550 485 456 3500 350( 2357 3400 340( 0 0 0 0 700 550 0 0 550 ! 13 3500 185 482 3500 08-Jul-2000 2029 ' 3400 330( 0 550 490 455 3500 350( 2345 3400 340( 0 0 0 0 700 550 0 0 550107 3500 190 482 3500 (~.J ~-~0('~0 2006 3400 330( 0 550 490 451 3500 350( 2323 3400 340( 0 0 0 0 700 550 0 0 550 106 3500 190 470 3500 1 ~.,-Jul-2~l 1996 3400 330( 0 550 4~0 451 3500 350( 2312 :3400 340( 0 0 0 0 700 550 0 0 550 112 3500 20(~ 466 3500 ! I -Jul-2~.~9 1987 3400 330( 0 550 490 448 3500 350( 2300 3400 340( 0 0 0 0 700 550 0 0 550 126 3500 205 443 3500 12-Jtll-20C~ 1977 .3400 332! 0 550 490 447 3500 350( 2283 3400 340( 0 0 0 0 700 550 0 0 550 129 3500 220 428 3500 13.Jul-~O00 1977 3400 332! 0 550 490 448 3500 350( 2283 3500 340( 0 0 0 0 700 555 0 0 550130 3500 225 421 3500 14-J~tl- 20~9 1974 3400 3321 0 550 490 449 3500 350( 2279 3500 340( 0 0 0 0 700 555 0 0 550 125 3500 225 415 3500 15.-$ul.2(?~.~) 1955 3350 335( 0 550 490 444 3500 350( 2258 3500 340( 0 0 0 0 700 555 0 0 550 124 3500 235 414 3500 16-J~1-20~t) 1954 3350 335( 0 550 490 445 3500 350( 2255 3500 340( 0 0 0 0 700 555 0 0 550 118 3500 235 413 3500 I ?.Jul..201',a9 1937 3350 335( 0. 550 490 442 3500 350( 2238 3500 340( 0 0 0 0 700 555 0 0 550 119 3500 235 411 3500 I ~-Jul-3¢;~'~ 1945 3350 335( 0 550 4~0 445 3500 350( 2241 3500 340( 0 0 0 0 700 555 0 0 550 117 3500 235411 3500 19-.$uI.2~.~.~ 1927 3350 335( 0 550 490 440 3500 350( 2222 3500 340( 0 0 0 0 700 555 0 0 550 118 3500 230 407 . 3500 20-.1'ul-200() 1911 3360 332.~ 0 495 495 437 3495 350( 11200 3500 340( 0 0 0 0 700 56(1 0 0 550 ! 19 3495 235 401 3500 ~ 1 .Jul..~ .~.90 1872 3360 330( 0 500 500428 3450 3475 2148 3500 340( 0 0 0 0 700 56(10 0 550 115 3450 240390 3500 22-J~tl- 2 f:~:~'~ 1895 3360 330( 0 500 500436~ 3450 349~ 2167 3150 340( 0 0 0 0 705 560 0 0 550 12'/ 3450 243 387 3525 23-.A~l-.2t'~ 1908 3360 330( 0 500 500 441 3450 349~ 2180 3150 340( 0 0 0 0 705 560 0 0 550 128 3450 243 383 3525 24-A~1-2000 1905 3360 331.~ .0 500 500 441 3495 350( 2172 3150 340.~ 0 0 0 '0 700 560 0 0 550 118 3475 245 357 3540 ~ 5.J~tl-~0{',,O 1910 3360 332.~ 0 500 505 443 3450 350(.2170 3175 341.~ 0 0 0 0 705 560 0 0 550 117 3475 245364 3550 26-J ul- 2 f~'~'~ 1905 3375 333.~ 0 500 502 442 3495 350( 2157 3200 342.~ 0 0 0 0 702 560 0 0 550 121 3475 245 355 3550 27.-Jul..2~.~ 1906 3350 335( 0 500 502445 3500 350(2153 3400 340( 0 0 0 0 702 560 0 0 550 139 3500 255353 3500 28-Ju]-2000 1886 3350 335( 0 500 502 441 3500 350( 2124 3400 340( 0 0 0 0 702 560 0 0 550 140 3500 255 358 3500 ~9.J~tl-~000 1931 3350 335( 0 500 502 452 3500 350( 2179 3400 340( 0 0 0 0 702 56~ 0 0 550 126 3500 255 360 3500 30.-Jul-~¢~')0 1917 3350 335( 0 500 502 448 3500 350( 2155 3400 340( 0 0 0 0 702 56~ 0 0 550 121 3500 255 360 3500 .~ 1 -Jul..200~) 1922 3350 335( 0 500 502 451 3500 350( 2158 3400 340( 0 0 0 0 702 56(1 0 0 550 129 3500 255 354 3500 TOTAL 58,762 0 13,487 67,646 0 0 0 3,740 13,021 MAXIMUM 3,400 3,400 550 505 3,500 3,500 3,500 3,425 0 0 705 560 0 550 3,500 255 3,550 AVERAGE i,896 3,375 3,338 0 530 494 435 3,493 3,499 2,182 3,391 3,401 0 0 0 0 701 555 0 0 550 121 3,493 217420 3,506 # DAYS 31 0 31 31 0 0 ~8/08/2000 ' 0 31 3 ! ~41-23 shut in due to annular communication problem. ~34-23 has developed an annular corrnnunication problem. AOGCC notified on 12/12/99. Verbal approval to congnue to inject received f~m Mr. Wondzell on 12/14/99, WATER INJECTI.ON REPORT PLATFORM C C23-23 C41-23 (24-23 C34-23 ACT ACT ACT ACT INJ INJ ANNU INS INS ANNU INJ INJ ANNU ~ INJ ANNU TOTAL MAXIMUM AVERAGE # DAYS 0 1300 130( 0 1300 130( 0 1300 130( 0 1300 130( 0 1300 130( 0 1300 130( o 1300 130( 0 1250 120( 0 1250 120( 0 1200 120( 0 1200 119-~ 0 1175 117.~ 0 !175 116( 0 1160 115( 0 1160 115( 0 1160 115{ 96 1160 115( 1533 1160 115( 2401 1160 115( 2339 3300 330( 2270 3300 33O( 2219 3300 330( 2210 3350 330( 2182 3350 335( 2162 3350 335( 2141 3350 335( 1867 3400 340( 0 3400 340( 0 3400 340( 0 3400 340( 21,420 3,400 3,400 714 2,007 1,999 11 o 550 50( o 550 50( o 55o 50( o 550 50( 0 550 o 550 . o 550 0 550 0 555 0 555 o 55o 4g~ 0 550 480 0 550 490 0 550 44 0 550 490 0 550 490 0 550 490 0 550 490 0 550 490 0 550 490 0 550 4~0 o 550 490 0 55O 490 0 550 490 0 550 490 0 550 490 0 550 4~0 o 550 490 0 550 490 o 555 500 o 550 493 0 o 120o 125o o 1200 1250 o 12oo 125o 0 120o 125(] o 12oo 125o 0 1200 1250 0 1200 1250 0 1150 0 1150 120C 0 1150 120c 0 1150 120C 0 1150 1195 0 1150 119~ 0 1140 IlgC 0 1140 !19(] 0 1140 119C 46 1140 1 332 ! 140 ! 19~ 464 1140 119C 488 3450 345C 467 3450 345(] 464 3450 3450 469 3500 350~ 465 3500 350~ 462 3500 350~ 458 3500 3500 4O4 35OO 350~ 0 3500 350~ 0 3500 350~ 0 3500 350~ 4,519 3,500 3,500 151 2,016 2,048 11 0 800 100( 0 800 100( 0 800 100( 0 800 100( 0 800 100~ 0 800 100( 0 8OO 100( 0 750 975 0 750 975 0 740 96( 0 700 95( 0 700 95C 0 700 95C 0 700 ~4C 0 700 94( 0 700 94( 155 7OO 94~ ~4 700 94C 2528 7OO 94( 2486 3350 300( 2463 3350 300( 2445 335O 300( 2457 3400 340( 2437 3400 340( 2412 3400 340( 2397 3400 340( 2095 3400 340( 0 3400 340( 0 3400 340( 0 3400 340( 3,4OO 3,4OO 730 1,713 1,820 11 0~1~2000 C41-23 shut in due to annular eon'~unication problem. ~34-23 has developed an annular oxrmunlcatlon problem AOGCC notified on 12/12/~9. Verbal approval to con6nue to inject received from Mr. Wondzell on 12/14/99. Platform "C" injectors shut-in flora May 11 thru Jm~e 16 due to pump failm~ (23-26 C41-26 C44-14RD ACT ACT ACT INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU 0 o o o 0 0 0 o o o o 0 0 0 0 o 0 o o o 0 o o o 0 0 0 o 0 0 0 0 0 0 0 0 o o 0 o o o 0 o o o 0 0 0 o o o 0 0 o 0 o o o 0 0 o o 0 o o 0 0 700 55(] 0 700 550 0 700 55(] 0 700 550 0 7OO 550 0 7OO 550 0 700 550 0 7OO 550 0 700 550 0 695 55(] 0 700 55(] 0 700 550 0 700 55(] 0 700 55(] 0 700 55(] 0 70O 55(] 0 700 550 0 700 550 0 700 55(] 0 7O0 55(] 0 700 55(] 0 700 550 o 700 550 0 700 55(] 0 700 55(] 0 700 55(] 0 700 55(] 0 700 55(] 0 700 55(] 0 700 55(] 0 7O0 55O 0 700 550 0 0 0 550 0 0 550 0 0 550 0 0 ' 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 55O 0 0 55O 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 o 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 o 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 C24A-23 C24A-14 ACT ACT l~J ]~NJ ANNU INJ . INJ ANNU 0 500 4lC 0 500 410 0 500 41C 0 500 41C 0 500 410 0 500 410 0 500 41C 0 255 425 0 255 425 0 255 430 0 205 432 0 200 435 0 175 438 0 150 44C 0 150 44C 0 150 44C 35 150 44C 206 150 44C 171 150 44C 148 3450 345C 132 3450 345C 119 3450 345C 122 3450 10( 113 3500 105 115 3500 12C 123 3500 135 92 3500 14C o 3500 14(] 0 3500 14C 0 3500 14(] 1,376 3,500 3,450 46 1,468 649 11 0 0 7: 0 0 8! 0 0 98 0 0 98 0 0 91 0 0 91 686 0 850 0 578 3500 350( 576 3500 350( 549 3500 350( 537 3500 516 3500 495 3500 476 3500 417 3500 0 3500 0 3500 0 3500 5,680 3,500 3,50(] 210 1,283 375 10 May~2000 Ol -Ma~-2000 02 .M ay-2OIX~ 03 -May-2000 LM-May-2000 05-M~,-2000 06~May-:~000 07-~tay.2000 08-May-2000 09-May-2000 I O.May.2000 ! I -M~--2000 ! 2-May-2000 13-M~,-2000 14-1V[ay-2000 15.May. 2000 16-May-2000 17-May-2000 1 $.May.2000 19-May-20® 20-May-2000 2 ! -May-2000 22-May-2000 23 -May. 20¢K} 24-May-2000 25-May-2000 26.May.2000 27-May-2000 2g-May-2000 29-May-20£R) 30:May..2000 ..... 31 .May; 2000 TOTAL AVERAGE · · #DAYS WATER INJECTION REPORT PLATFORM C C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 · ACT ACT ACT ACT ACT ACT ACT ACT ~J ~J AIN,rI~u ~J ~J AN~U ~J ~l ANNU ~l INJ ANNU ~J ~l ANNU INI ~l ANNLI ~l ~J ANNU ~l RqJ ANNU 1743 3340 3300 1814 3340 3300 1873 3340 3300 1827 3340 3300 1810 3340 3300 1703 3340 3300 1831 3340 3300 1846 3340 3300 I836 3340 3300 366 3340 3300 0 2100 2050 0 1900 1895 0 1840 1840 0 1750 1760 0 1710 1710 0 1700 1690 0 ! 650 1640 0 1650 1640 0 165O 1 640 0 1650 1640 0 1650 1640 0 1650 1640 0 1650 1640 0 1650 1640 0 1400 1400 0 1400 1400 0 1400 1400 0 1350 1350 0 1350 1350 0 1350 1350 0 1300 130(} 16~49 3,340 3,300 537 2,166 2,149 10 0 500 520 0 500 520 0 500 525 0 50O 525 0 500 525 0 500 525 0 500 525 0 500 525 0 5OO 525 0 5OO 525 0 550 525 0 550 520 0 550 525 0 550 525 0 550 525 0 560 525 0 550 520 0 ' 550 520 0. 550 520 0 550 520 0 550 520 0 550 520 0 550 520 0 550 520 0 550 510 0 550 510 0 550 510 0 550 500 0 550 500 0 550 500 0 550 500 0 560 525 0 534 519 0 374 3500 3500 393 3500 3500 404 3500 3500 393 3500 3500 388 3500 3500 385 3500 3500 394 350O 3500 401 3500 3500 397 3500 3500 79 3500 3500 0 1500 1500 0 1400 1450 0 1410 1410 0 1400 1400 0 1360 1390 0 1350 1360 0 1350 1350 0 1350 1350 0 1350 1350 0 1350 1350 0 1350 1350 0 1350 1350 0 1350 1350 ' 0 1350 1350 ':i0 1300 1300 /0 1300 1300 (,0 1250 1250 ~' 1250 1250 0 1250 1250 0 1250 1250 0 1200 1250 3,608 3,500, 3,500 116 2,033 2,037 10 1949 3450 3400 2010 3450 3400 2102 3450 3400 2060 3450 3400 2035 345O 34OO 2028 3450 3400 2074 3450 3400 2104 3450 3400 2090 3450 3400 417 3450 3400 0 1500 1650 0 1350 1525 0 1450 1450 0 1200 1400 0 1300 1350 0 1300 1310 0 1200 1275 0 i 1200 1275 0 1200 1275 0 1200 1275 0 1200 i275 0 1200 1275 0 1200 1275 0 1200 1275 0 900 1100 0 900 1100 0 900 fl00 0 900 Ii00 0 900 1100 0 : 850 1050 0 800 1000 18,869 3,450 3,400 609 1,882 1,950 10 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 O. 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 670 550 670 550 670 550 670 550 670 55~ 670 550 670 550 670 550 670 550 670 550 680 50~ 675 550 675, 54~ 675 550 675 550 675 550 675 550 675 550 675 550 675 550 675 550 675 550 675 550 675 550 1150 550 1000 550 1250 550 1400 550 1500 550 1200 550 700 550 0 !,500 550 0 786 548 0 0 0 550 0 O 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 840 I~00 550 0 0 550' 0 0 55O 0 0 550 0 0 550 0 0 550 340 1~00 550 1,020 !,400 550 '0 0 550 0 0 550 o o 55oi 0 0 550 0 0 550: 0 0 550 0 0 550 0 0 550 0 0 550 2~00 1,500 550 73 143 550 3 !13 350030 112 350030 114 350030 - 113 350030 113 350030 113 350030 113 350030 113 350030 113 350030 113 350030 0 2200257 0 1855' 293 0 1700310 0 1550325: 0 1440335 0 1325345 0 1255350 0 1255350 o 1255350 0 125535( 0 125535{ 0 1255350 0 125535( 0 125535( 0 725 38( 0 725 0 500 40( 0 400 40( 0 400 40C 0 250 41( 0 500 41( 1,130 3,500 410 36 1,891 250 10 0611412000 CAI-23 shut in duc to annular communication problem. C34-23 has developed an, annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. All Plntform "C" injectors shut-in from Mayl I thru today due to pump failure. Pump has been repaired and is currently being installed. April-2000 01-A ~'-2O00 02-A ~r-2000 03-A )r-2000 04-A )r-2000 05-A ~r-2o00 06.A )r-2000 07-A x-2000 08-A ~r-2000 09-A ~r-2000 IO-A ~r-2000 I I-A )r-2000 12-A )r-2000 13-A ,r-2000 14-A )r-2000 15-A )r-2000 16-A )r-2000 17-A ~r-2000 18-A ,r-2000 19-A )r-2000 20-A ~-2000 21 -A )r-2000 22-A )r-2o00 23-A ,r-2000 24-A ,r-2000 25-A ,r-2000 26-Apr-2000 27-Apr-2000 28-Apr-2000 29-Apr-2o00 30-Apr-2000 TOTAL MAXIMUM AVERAGE # DAYS C23-23 ACT INJ INJ ANNU 1817 3300 3300 1762 3300 3325 1834 33O0 3325 1850 3300 3325 1858 3300 3325 1839 33OO 3325 1841 3300 3325 1837 3300 3325 1846 3300 3325 1826 33OO 3325 1838 3300 3322 1838 3300 3323 1823 3300 335C 1833 3375 335C 1800 3375 335£ 1784 3375 335C 1779 3350 330C 1774 335O 330C 1785 3350 330( 1783 3350 330( 1293 3350 330( 1878 3350 330( 1622 3350 330( 0 2100 330( 0 0 330( 459 0 3300 1953 3325 3275 1918 3325 3300 1860 3340 3300 1848 3340 3300 49,178 3,375 3,350 1,639 3,064 3,315 28 C41-23 INJ INJ ANNU 0 550 520 0 550 52C 0 550 515 0 550 515 0 550 515 0 550 515 0 550 513 0 550 513 0 550 513 0 550 513 0 550 513 0 550 52( 0 550 523 0 550 523 0 550 523 0 550 523 WATER INJECTION REPORT PLATFORM C C24-9~ ACT INJ INJ ANNU 394 3500 35O0 380 3500 397 3500 350~ 399 3500 350( 401 3500 350( 397 35OO 350( 395 3500 350( 396 3500 350( 399 3500 350( 395 350O 35O( 395 3500 35® 393 3500 3500 392 3500 350( 395 3500 350( 389 3500 3500 383 3500 35: 382 3450 34 381 3450 345q 389 3450 345q 387 3450 3450 288 3450 3450 402 3450 3450 352 3450 345( 0 550 51C 0 550 51C 0 550 52( 0 550 52( 0 550 52( 0 550 52( 0 550 52( 0 550 52( 0 500 520 0 500 520 0 5OO 52O 0 500 520 0 500 520 0 500 520 0 550 525 0 540 519 0 II 39; 4O( 39~ 399 10,584 353 28 05/10/2000 C41-23 shut in due to ~nulm mmmuni~on probit. ~ C34-23 h~ develo~ ~ ~nul~ ~mmuni~on probit. A~C no~ on IWI~. V~ ~pm~ to ~n~ C34-23 INJ INJ ANNU 1982 3450 34OO 1932 3450 34OO 2019 3450 3400 2038 3450 3400 2050 3450 3400 2025 3450 340(] 2024 3450 34O0 2025 3450 34O0 2036 3450 340{3 2009 3450 34O0 2025 3450 34O0 2024 3450 34O0 2016 3450 34O0 2023 3500 342C 1954 35OO 342~ 1933 3500 3420 1934 3450 340(3 1932 3450 340(] 1919 3450 3375 1926 3450 3375 1390 3450 3375 2010 3450 3375 0 0 0 0 o o o 0 0 0 0 0 0 0 0 0 0 0 0 0 · o o 0 0 0 0 o 0 0 0 0 0 o o .0 0 0 0 0 o 0 0 0 64O 5O0 0 64O 5O0 0 650 0 650 50~ 0 650 0 650 50~ 0 650 50~ 0 650 50~ 0 650 50( 0 650 50~ 0 '650 50C 0 650 50~ 0 650 50~ 0 .650 o 650 5o~ 0 650 0 650 0 650 0 650 0 650 0 0 0 550 0 0 550 0 O- 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 ' 0 550 0 o 550 o o 550 0 0 550 0 0 550 ' 0 0 550 0 0 550 0 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 550 0 55O 0 550 0 550 550 550 150 3500 55 150 3500 55 150 3500 55 150 3500 6(] 150 3500 6C 150 3500 6C 150 3500 6C 107 3500 6C 108 3500 6C 108 3500 6(: 108 3500 6C 107 3500 6~ 107 3500 6~ 107 3500 108 3500 108 3500 107 3450 110 3450 108 3450 113 3500 4~ 80 3500 4~ 147 3500 4~ 112 3500 4C 0 2300 4C 0 0 4C 112 0 4C !13 3500 114 3500 2( 113 3500 3C 113 3500 3( 3,360 3,500 65 112 3,222 49 28 March-2000 OI-Mar-2000 02-Mar-2000 03-Mar-2000 04-Mar-2000 OS-Mar-2000 06-Mar-2000 07-Mar-2000 08-Mar-2oO0 09-Mar-2o00 I O-Mar-2000 ! l-Mar-2000 12-Mar-2o00 13-Mar-2000 14-Mar-2oO0 15-Mar-2oO0 16.Mar-2o00 17-Mar-2000 18-Mar-2000 19-Mar-2000 20-Mar-2000 21-Mar-2oO0 22-Mar-2000 23-Mar-2000 24-Mar-2oO0 25-Mar-2000 26-Mar-2oO0 27-Mar-2000 28-Mar-2000 29-Mar-2o00 30-Mar-2000 3 ! -Mar-2000 TOTAL MAXIMUM AVERAOE # DAYS 04112/2000 C23-23 ACT [NJ [NJ ANNU 1802 3240 320( 1820 3250 322~ 1807 3250 3222 1924 3350 330( 1940 3350 332C 2794 3150 310( 667 3200 315( 1637 3150 314( 1664 3150 314( 1652 3150 314( 1644 3150 314( 1646 3150 314( 1634 3150 314( 1590 3150 314( 1617 3150 314C 1621 3150 315C 1771 3275 323C 1761 3275 324( 1787 3300 325C 1778 3300 325C 1790 3350 330( 1846 3350 330C 1805 3350 330~ 1814 3350 330( 1801 3300 330( 1812 33OO 330( 1777 3300 330( 1718 3300 320( ! 704 330O 320( 1748 3250 325( 1687 3300 327~ 54,058 3,350 3,320 1,744 3,250 3,219 31 WATER INJECTION REPORT PLATFORM C C41-23 ACT INJ [NJ ANNU 0 550 505 0 55O 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 $10 0 550 510 0 550 510 0 550 515 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 550 510 0 52O 510 0 520 500 0 52O 5O0 0 550 5O0 0 550 5O0 C34-23 ACT INJ [NJ ANNU C23-26 ACT INJ INJ ANNU C41-26 ACT INJ INJ ANNU 0 50 0 645 50( 0 0 0 0 640 5o( ] 0 0 {~ 0 640 50( 0 0 0 o 64o 50( 0 0 .0 0 640 5OO C44-14RD ACT INJ INJ ANNU C24A-23 ACT ~N~J [NJ ANNU 0 550 515 0 547 509 0 377 3440 345C 384 35OO 35O( 382 35O0 35o( 386 3500 350( 385 35OO 3500 380 3500 3500 379 3500 35O0 384 3500 35oo 388 3500 3500 386 350O 35OO 383 3500 350( 384 3500 350( 388 3500 350( 370 35O0 350( 380 3500 350( 382 3500 350( 393 3500 350~ 391 3500 350( 388 3500 350~ 387 3500 350( 386 3500 350( 393 3500 385 3500 350( 387 3500 350( 384 3500 350( 387 3500 350( 386 3500 350( 390 3500 350( 391 3500 350( 386 3500 350( 375 3500 350( i 1,927 3,500 3,500 385 3,498 3,498 31 1998 3425 3375 2041 3450 340( 2037 3450 340C 20.54 3450 3401: 2O56 3450 340( 2021 3425 340( 2022 3450 340( 2044 3450 340( 2082 3450 340( 2061 3450 340( 2049 3450 340( 2024 3450 340C 1966 3450 340( 1896 3450 340~ 1917 3450 340~ 1943 3420 34O0 2002 3440 34O0 2009 3440 34O0 2003 3450 34O0 2006 3450 34O0 2001 3450 340(] 2040 3450 34O0 1994 3450 340(] 2009 3450 34O0 1997 3400 34O0 2014 3400 340C 1953 3400 34O0 19'/5 ' 3400 34O0 1962 3400 340~ 1958 3450 340(] 1866 3425 34O0 62,O00 3,450 3,4OO 2,000 3,438 3,399 31 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 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 0 0 640 5O0 640 500 640 5OO 640 soo 640 500 640 50( 640 50( 640 50( 640 50( 640 50( 640 50~ 640 50C 640 50C 640 500 640 50C 640 50C 640 50C 640 5O0 640 5O0 640 50(] 500 50C 5OO 50~ 500 5O0 500 50C 640 5O0 640 5O0 0 5O 0 0 2 0 0 o 645 5O0 0 622 500 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0. 550 0 O' 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0. 550 o 0 550 0 0 550 0 160 4500 294 4550 248 46OO 72 3500 124 3500 136 3500 143 3500 119 3500 52 . 2650 19 2650 0 265O 0 2650 0 2650 0 2650 138 3500 174 3800 248 4050 240 4100 243 4250 99 3500 138 3500 142 3480 153 4000 310 4300 303 4500 303 4500 161 4500 97 3500 126 3500 147 3500 150 35O0 4,539 4,600 0 146 3,646' 0 27 :41-23 shut in due to annular conununication problem. :34-23 has developed an annular communication problem. AOOCC notified on: 12/12/99. Verbal approval ;o condnue to inject reoeived from Mr. Wondzell on 12/14/99. RECEIVED Alaska Oil & Gas Cons. Commis~xt Anchorage ~ - ,~bruav/-2000 OI-Feb-2000 02-Feb-2000 03-Feb-2000 04-Feb-2000 OS-Feb-2000 06-Feb-2000 07.Feb-2000 08-Feb-2000 09-Feb-2000 I O-Feb-2000 i I-Feb-2000 12-Feb-2000' 13 -Febo2000 14-Feb-2000 I S-Feb-2000 ! 6-Feb-2000 17-Feb-2000 ! 8-Feb-2000 19-Feb-2000 20-Feb.2000 21 -Feb-2000 22-Feb-2000 23-Feb-2000 24-Feb-2000 2S-Feb-2000 26-Feb-2000 27-Feb-2000 28-Feb-2000 29-Feb-2000 TOTAL MAXIMUM AVERAGE · #DAYS ..'" *' · 03/09/2000 .. WATER INJECTION REPORT PLATFORM C C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 ACT ACT ACT ACT ACT ACT ACT ACT INJ INJ ANNU INJ INS ANNU INJ INJ ' ANNU INS INJ ANNU [NJ [NJ ANNU [NJ [NJ ANNU [NJ [NJ ANNU [NJ INJ 0 3175 3175 0 575 532 373 3475 349(] 1926. 3450 3400 0 50 0 0 640 50~ 0 0 .550 ! 60 4500 0 0 1770 0 570 528 375 3480 3495 1930 3460 3400 0 50 0 0 640 50~ 0 0 550 294 4550 0 0 1750 0 575 530 380 3500 350~ 1952 3450 3425 0 0 0 0 640 50~ 0 0 550 248 4600 0 0 1700 0 570 53(3 381 3500 350( 1948 3450 3425 0 0 (3 0 640 50( 0 0 550 72 3500 0 0 170~ 0 560 525 378 3500 350( 1934 3450 3420 0 0 0 0 640 50C 0 0 550 124 3500 0 1600 1675 0 560 52(3 377 3500 3500 1933 3450 3425 0 0 (~ 0 640 50( 0 0 550 136 3500 0 1600 1650 0 560 52(3 378 3500 350( 1926 3450 3425 0 0 0 0 640 50~ 0 0 550 143 3500 0 1600 1625 0 560 52C 305 3500 350( 1557 3450 3425 0 0 (3 0 640 50( 0 0 550 i 19 3500 0 1600 160~ 0 520 52(: 341 3500 350( 33 2900 3425 0 0 (3 0 640 50( 0 0 550 52 2650 0 1600 160~ 0 520 52{ 401 3500 350C 2047 3450 3425 0 0 (3 0 640 50( 0 0 550 19 2650 0 1600 160~ 0 520 52¢ 379 ' 3500 350( 2036 3470 3425 0 0 (3 0 640 500 0 0 550 0 2650 0 1600 160( 0 520 52{ 391 3500 350( 2072 3470 342(3 0 0 ¢ 0 640 50( 0 0 550 0 2650 0 1600 160( 0 520 52C 391 3500 350( 2074 3450 '342(3 0 0 (3 0 640 50( 0 0 550 0 2650 0 1600 160~ 0 520 52C 382 3500 350( 2026 3450 3420 0 0 (3 0 640 50C 0 0 550 0 2650 0 1600 160~ 0 520 520 381 3500 350( 1991 3500 3420 0 0 0 '0 640 50( 0 0 550 138 3500 0 1450 148(3 0 550 515 382 3500 350( 2012 3470 3420 0 0 (3 0 640 50C 0 0 550 174 3800 0 1500 148(3 0 550 51~ 382 3490 350( 201 ! 3460' 3400 0 50 0 0 645 50~ 0 0 550 248 4050 0 1500 150~ 0 550 51(3 375 3485 349~ 1973 3450 3400 0 50 0 0 648 50~ 0 0 550 240 4100 0 1500 1475 0 550 51(3 377 3470 3475 1989 3450 3400 0 50 0 0 647 50(] 0 0 550 243 4250 0 1450 145{~ 0 550 .51(3 380 3485 3482 1982 3450 3400 0 50 0 0 650 500 0 0 · 550 99 3500 0 1450 145(3 0 550 510 384 3485 3485 1999 3450 3400 0 50 0 .0 650 50~ 0 0 550 138 3500 · 0 1450 142~0 0 550 51(3 382 3475 ' 3590 1993 3450 3400 0 50 0 0 650 500 0 0 550 142 3480 0 1400 1 40~ 0 550 508 328 3475 349~ 1653 3450 3400 0 50 0 0 650 50~ 0 0 550 153 4000 2066 3200 1400 0 550 509 382 3500 3490 2002 3500. 3400 0 .50 0 0 650 500 0 0 550 310 4300 1998 3200 140( 0 550 509 375 3500 349( 1994 3500 340~ 0 50 0 0 650 500 0 0 550 303 4500 1919 3200 140( 0 550 50! 375 3500 349( 1999 3500 340(1 0 50 (3 0 650 50( 0 0 550 303 4500 1882 3200 140( 0 550 50! 377 3500 349( 2008 3500 340~ 0 50 (3 0 650 50( 0 0 550 161 4500 1835 3200 140( 0 550 50~ 373 3500 3490 1992 3500 3400 0 50 (3 0 650 50( 0 0 550 97 3500 1811 3200 140( 0 550 508 376 3500 3490 2003 3500 . 3400 0 50 C 0 650 50( 0 0 550 126 3500 I 1,511 0 10,861 54,995' . 0 0 0 4,242 3,200 3,175 575 532 3,500 3,590 3,500 3,425 50 0 650 500 0 550 4,600 397 1,727 1,597 0 547 516 375 3,494 3,498 1,896 ,3,446 3,411 0 26 0 0 644 500 0 0 550 146 3,656 6 0 29 29 0 0 0 25 -23 shut in due to annular communication problem. -23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval t.o continue to inject received from Mr.,Wondzell on 12/14/99. · 23 down for flanse repairs. January-2000 I C23-23 0 I-Jan-2000 02-Jan-2000 03-Jan-2000 04-$an-2000 05.jnn-2000 06-Jan-2000 07-Jan-2000 0g-Jan-2000 09-Jan-2000 I O-Jnn-2000 I i-Jan-2000 12-Jan-2000 13-Jnn-2000 14-Jan-2000 ! 5-Jan-2000 16-Jan-2000 17-Jan-2000 i g-Jan-2000 ! 9-Jnn-2000 20-Jan-2000 21 -Jan-2000 22-Jnn-2000 23-Jan-2000 24-$an-2000 25-Jan-2000 26-Jan-2000 27-Jan-2000 28-Jnn-2000 29-Jan-2000 30-Jan-2000 3 I-Jan-2000 TOYAL MAXIMUM AVERAGE # DAYS 02/10/2000 C41-23 WATER INJECTION REPORT PLATFORM C C24-23 C34-23 C23-26 ACT INJ [NJ ANNU ACT ACT 1NJ IN] ANNU INJ INJ ANNU 1950 3560 3425 1955 3560 3425 1931 3560 3425 1942 3560 3425 1940 356O 3435 1910 3500 3425 ACT C41-26 1428 3190 3075 1433 3190 3075 1419 3190 3075 1429 3190 307~ 1427 3190 307~ 1421 3200 307~ 1406 3200 3075 1392 3200 3075 1389 3200 310C 1384 3200 315( 1386 3200 315{ 1398 3200 315( 1396 3200 315( 1411 3200 315C 1407 3200 315£ 1410 3200 315C 1408 3200 315C 1405 3200 315¢ 1410 3200 315¢ 1406 3200 315C 1399 3200 315C 1408 3180 3145 1417 3190 315¢ 1388 3175 3172 1392 3175 3172 585 3175 3175 0 3175 3172 0 3175 3175 0 3175 3175 0 3175 3175 0 3175 3175 0 580 650 0 580 650 0 580 650 0 580 650 0 580 650 0 580 650 0 580 650 0 580 650 0 525 650 0 530 530 0 540 530 0 575 535 0 575 535 0 575 535 o 575 535 0 575 535 0 575 535 0 575 535 0 575 540 0 575 532 395 3500 3500 396 3500 3500 391 3500 3500 393 3500 35O0 392 3500 3500 390 35OO 3500 387 3500 3500 381 3500 3500 381 3500 3500 381 35O0 35OO 381 3500 3500 382 3500 3500 379 3500 3500 383 3500 3500 381 3500 3500 382 3500 3500 380 350O 3500 383 3500 3500 382 3500 3500 381 3500 3500 78 2300 1950 0 23O0 1950 0 1900 1750 352 1750 1700 2155 3450 3400 2100 3460 3400 2079 3460 34OO 2088 3460 3400 2069 3460 34OO 2064 3460 3400 2054 3460 3400 2050 3460 3400 2049 3500 3425 2031 3465 3410 · 2020 3475 3425 2030 3460 3410 2039 3470 3425 1986 3450 3410 1988 3450 3400 1971 3450 3400 1937 3450 3400 1937 3450 3400 1925 3450 3400 1926 3450 3400 1918 3450 3~00 INJ INJ ANNU 0 50 0 5O 0 50 0 50 0 50 0 0 ACT INJ [NJ "'ANNU 0 650 45¢ 0 650 45( 0 650 450 G 0 650 450 0 0 630 450 0 0 630 450 0 630 450 0 630 450 0 630 450 0 630 500 0 640 50~ 0 640 50C 0 640 50C 0 640 50~ 0 640 50~ 0 640 50C 0 640 50~ 0 640 50C 0 640 50C 0' 640 50~ C44- ! 4RD ACT [NJ INJ ANlqU C24A-23 35,754 3,2OO 3,175 1,153 3,191 3,135 26 379 3500 3500 381 3490 3500 383 3500 3500 375 3490 3500 376 3470 3475 374 3475 3490 368 3475 3490 370 3475 3490 368 3475 3490 370', 3475 3490 370 3475 3490 ACT INJ INJ ANNU 0 575 522 0 575 515 0 575 538 0 575 538 0 575 538 0 575 532 0 575 532 0 575 532 0 575 532 0 575 532 0 575 532 0 580 650 0 572 567 0 54,474 3,560 3,435 !,757 3,296 3,207 I 1,815 3,5oo 3,500 381 3,494 3,497: 31 · 0 0 0 o * 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 50 0 50 0 50 0 50 0 50 0 50 0 50 0 50 0 50 0 50 0 50 0 50 0 50 0 0 27 0 0 640 50~ 0 640 ' 50C 0 , 640 50G 0 .640 50C 0 640 50C 0 640 50G 0 640 0 640 50~ 0 640 500 0 640 500 0 640 500 0 650 50C 0 639 485 550 550 550 550 '550 550 550 550 550 550 550 550 550 550 550 550 550 550 550 550 550 550 550 550 550 550 550 550 550 550 550 0 0 550 0 0 550 0 175 3500 0 175 350O 0 173 35O0 0 174 350O 0 174 35O0 0 173 3500 0 173 3500 0 171 35OO 0 171 3500 171 3500 172 3500 173 3500 169 3500 172 3500 170 3500 171 3500 169 3500 170 3500 170 3500 167 3500 167 3500 168 3500 168 3500 163 3500 166 3475 162 3490 238 4500 370 4500 331 4500 302 4500 419 4500 6,087 4,500 0 ! 96 3,660 0 31 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCc notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzall on 12/14/99: C23-23 down t'or five days due to flnnse repairs and expected to be back online in mid-February. ~34-23 shut in t'or two days for survey. December-99 ! C23-23 INJ INJ ANNU C41-23 ACT [NJ [NJ WATER INJECTION REPORT PLATFORM C C24-23 ACT [NJ [NJ ANNU C34-23 ACT [NJ [NJ ANNU 0 ! -Dec-99 02-Dec-99 03-Dec-99 04-Dec-99 05-Dec-99 06-Dec-99 07-Dec-99 08-Dec-99 ~9-Deo-99 0oDeco99 I-Dec-99 2-De¢-99 3 -Dec-99 4-De0-99 5 -Dec-99 6-De¢-99 7 -De¢-99 i 9-De0-99 20-De0-99 2 I-Dec-99 22-De¢-99 23-Dec-99 24-De0-99 25-Dee-99 26-Dec-99 27-Dee-99 28-De0-99 29-De~-99 30-De0-99 3 I-De0-99 TOTAL MAXIMUM AVERAOE # DAYS 1389 3175 310C 1394 3175 31O( 1394 3175 31O( 1392 3175 310( 1391 3175 31O( 1389 3175 31O( 1388 3175 31O( 1332 3175 310( 1386 3175 31O( 1388 3200 3050 1390 3200 3050 1391 3200 3O5O 1395 3200 3050 1386 3200 3050 1379 3200 3050 1382 3200 3050 1372 3200 3050 1364 3200 3050 1371 3200 3050 1391 3200 3050 1378 32OO 3050 1396 3200 3050 1383 3160 305O 1404 3170 3050 1391 3160 3050 1409 3195 3075 1425 3190 3060 1419 3190 3075 1413 3190 3075 1408 3190 3075 1423 3190 3075 43,113 3,200 3,100 !~91 3,187 3,069 31 0 575 650 0 575 650 0 575 650 0 575 650 0 575 650 0 575 650 0 575 650 0 575 650 0 575 650 0 525 650 0 525 65G o 580 65c .0. 580 65G 0 580 650 0 580 650 0 580 650 0 580 65e 0 580 65e 0 580 65C 0 580 65C 0 580 65C o 580 65C 0 575 65C o 575 65c 0 580 65C 0 580 65C 0 575 65C 0 580 65C 0 580 65C 0 580 65C 0 580 65C 0 580 650 0 575 650 0 383 3460 3475 39O 3460 3475 382 3500 3475 382 3500 3475 380 3500 3475 379 3500 3475 378 3500 3475 373 35OO 3475 383 3500 3475 386 3500 3500 386 3500 3500 386 3500 3500 388 3500 3500 385 3500 3500 382 3500 3500 379 3500 3500 374 3500 3500 371 3500 3500 375 3500 3500 380 3500 3500 379 35OO 3500 383 35OO 35O0 379 3450 3450 385 3475 3485 383 3450 3475 394 3500 3500 395 3500 3500 394 3500 35O0 390 3500 350C 387 3500 350C 392 35O0 350C ! i,883 3,500 3,500 383 3,493 3,490 31 1941 3525 1945 3525 1941 3500 1931 3500 1928 3500' 1931 3500 1928 3500' 1844 3500 1921 3500 1933 3500 1937 3500 20 1943 3500 34O( 1953 3500 340C 1938 3500 340C 1704 3500 34O( 1683 35O0 340C 1738 -3500' 34O( 1738 3500 34O( 1757 3500 340C 1814 3500 34O( 1807 35OO 34O( 1837 3500 34O( 1839 3525 340C 1882 3550 34O( 1869 3525 34O( 1907 3550 3422 1923 3555 342~ 19Il 3560 3422 1905 3560 3425, 1898 3560 3425 1930 356O 342 58,156 3,560 3~25 !,876 3,516 2~05 31 ACT C23-26 [NJ [NJ ANNU 0 50 0 50 0 50 0 50 0 50 0 50 0 50 0 50 ' 0 50 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 0 0 50 0 50 0 50 0 50 0 50 0 50 0 50 0 50 0 50 0 50 0 29 0 C41-26 ACT 0 645 45( 0 645 450 0 645 0 645 450 0. 645 .450 0 645 450 0 645 450 0 645 450 0 645 450 0 · 645 450 0 645 450 0 650 450 0 650 450 0 650 450 0 650 450 0 650 450 0 650 450 0 650 450 0 650 450 0' 650 450 0 650 450 0 650 450 0 650 450 0 .640 450 0 650 450 0 650' 450 0 65o 450 0 0 650 450 0 0 650 450 0 O 650 450 0 .0 650 450 0 0 650 450 0 0 648 450 0 C44- ! 4RD ACT [NJ [NJ ANNU C24A-23 ACT [NJ [NJ ~ 108 3460 150 3460 325 4500 376 4500 335 4500 317 4500 314 4500 309 4500 276 4500 89 3500 343 3500 297 4400 285 4450 277 4450 103 4450 0 4450 0 4450 140 4450 !09 4450 146 4450 ISi 4450 160 4450 162 3475 168 3490 167 ' 3475 171 3500 173 35OO 171 3500 171 3500 170 3500 174 3500 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 o o 55o! 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 o 550 0 0 550 0 0 550 0 0 550! 0 0 550: 0 0 55° 0 0 550 0 0 550 0 0 550 6,137 4,500 198 4,057 29 01/13/00 4 i-23 shut in due to annular communication problem. 34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. November-99 ACT INJ C23-23 INJ ANNU WATER INJECTION REPORT PLATFORM C C41-23 ACT INJ INJ C24-23 ACT [NJ INJ ANNU C34-23 ACT [NJ [NJ ANNU C23-26 ACT INJ [NJ ANNU C41-26 ACT [NJ [NJ ANNU C44-14RD ACT [NJ fNJ ANNU C24A-23 ? L ~ACT' INJ [NJ ANNU 01 -Nov-99 02-Nov-99 03-Nov-99 04-Nov-99 05-Nov-99 06-Nov-99 0T-Nov-99 08-Nov-99 09-Nov-99 ! 0-Nov-99 I I-Nov-99 12-Nov-99 13-Nov-99 14-Nov-99 15-Nov-99 16-Nov-99 17-Nov-99 18-Nov-99 19-Nov-99 20-Nov-99 21 -Nov-99 22-Nov-99 23 -Nov-99 24-Nov-99 25-Nov-99 26-Nov-99 27-Nov-99 28-Nov-99 29-Nov-99 30-Nov-99 TOTAL MAXIMUM AVERAGE # pAYS i 2/I 3/99 1316 3500 3110 1316 3500 3110 1313 3500 31lC 1365 3500 311C 1378 3500 311C 1386 3500 311C 1385 3500 311C 1380 3500 311C 1382 3500 311C 1381 3500 31lC 1379 3500 31lC 1376 3500 31lC 1379 3500 311C 1383 3500 311C 1373 3500 3110 1384 3500 3110 1369 3500 3110 1375 3500 3110 1359 3500 3110 1374 3500 3110 1375 3500 3110 1377 3500 311C 1375 3500 31lC 1388 3500 31lC 1379 3200 310C 1385 3200 310C 1394 3200 310¢ 1398 3200 310¢ 1391 3195 310( 1392 3195 310C 41,207 3,500 3,1 I0 1,374 3,440 3,108 3O 0 750 0 750 65C 0 750 65( 0 750 65( 0 750 650 O' 750 650 0 750 650 0 750 650 0 750 650 0 750 650 0 750 65( 0 750 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 750 65C 0 575 65¢ 0 575 65C 0 575 65( 0 575 65( 0 575 0 575 65C 0 750 650 0 715 650 0 394 3500 350( 398 3500 3500 395 3500 3500 396 3500 3500 397 3500 3500 400 3500 3500 401 3500 3500 394 3500 3500 396 3500 3500 397 3500 3500 393 3500 3500 391 3500 3500 393 350O 350( 392 35O0 350( 388 3500 350( 392 3500 350( 387 35O0 350C 387 3500 350(: 381 3500 350~ 387 3500 350C 387 3500 350( 388 35OO 350( 387 3500 350( 389 3500 350C 387 3490 350( 385 3~90 350( 388 3500 350C 389 3500 '3500 386 3490 3500 384 3490 350( · 11,729 3 500 3,500 391 3,499 3:500 30 ;41-23 shut in due to nnnular communication problem. 1940 3550 1962 3550 1965 3550 1978 3550 1987 3550 1998 3550 1993 3550 1978 3550 1959 3550 1964 3550 1974 3550 1976 3550 1976 3550 1978 3550 1960 3550 1979 3550 0 0 50 0 0 50 0 0 50 0 0 50 0 0 50 0 50 0 50 0 50 ' 0 0 50 0 0 50 0 0 50 0 0 50 0 0 50 0 0 50 '0 50 . 0 50 0 635 45C 0 635 45C · 0 635 45C 0 635 45C 0 635 45C 0 635 45( 0 635 45C 0 635 45C 0 635 45~ 0 635 45C o 635 45C 0 635 45C 0 635 45C 0 635 45C 0 635 45G 0 635 45G 1958 3550 1958 3550 1930 3550 1950 3550 1950 3550 1958 3550 1959 .3550 1973 3550 i951 3500 i955 3550 1963 3550 1963 3560 1956 3550 1951 3550 58.942 3,560 !,965 3,549 30 0 50 0 50 0 50 0 5O 0 50 0 0 50 0 .0 50 0 o 50 6 o 50 (~ 0 50 0 '0 50 0 0 50 0 0 50 0 0 50 0 0 50 0 0 50 : 0 0 0 635 450 0 0 635 450 0 635 450 0 635 45G 0 635 45G 0 635 450 0 635 45G 0 .635 450 0 645 45C 0 645 45G 0 645 45C 0 645 45C 0 645 45C 0 645 45G 0 0 645 450 0 0 637 450 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 o 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 244 3500 140 247 3500 140 230 3500 125 120 3500 125 114 3500 125 113 3500 125 114 3500 125 109 3500 125 109 3500 12~ 109 3500 125 III 3500 125 !!2 35OO 125 109 3500 125 I!0 3500 125 109 3500 125 112 3500 125 110 3500 125 112 3500 125 106 350O 125 112 3500 125 ill 3500 125 115 3500 125 0 0 550 0 0 550 .0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 415 3500 125 !12 3500 125 109 3490 75 il0 3475 75 113 3495 7C il6 35OO 65 114 3490 6G 114 3490 60 3,741 3,500 140 125 3,498 115 30 ,,. March-99 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 ~!iiiiiiiiiiiiiiiiiiii!!!ii!iiiiii!iii::::::::::::::::::::::::::::::::::::: ACT ACT ACT ACT ACT ACT ACT ACT i!ii~,'~.':~il~ilililili INJ INJ ANNU INJ INJ ANNU 1NJ INJ ANNU INJ INJ ANNU 1NJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU , 01-Maro99 1265 3250 3175 782 700 635 381 3500 3500 1932 3500 0 0 0 0 0 550 425 0 0 550 57 3500 0 02-Mar-99 1306 3250 3175 786 700 635 391 3500 3500 1981 3500 0 0 0 0 0 550 425 0 0 550 0 3500 0 03-Mar-99 1307 3250 3175 786 700 635 391 3500 3500 1990 3500 0 0 0 0 0 550 425 0 0 550 0 3500 0 04-Mar-99 1320 3250 3150 792 700 640 395 3500 3500 2014 3400 0 0 0 0 0 550 425 0 0 550 0 1600 0 05-Mar-99 1314 3250 3150 793 700 640 393 3500 3500 2007 3400 0 0 0 0 0 550 425 0 0 550 0 1400 0 06-Mar-99 1316 3250 3150 791 700 640 392 3500 3500 2015 3400 0 0 0 0 0 550 425 0 0 550 371 3500 0 07-Mar-99 1311 3250 3150 790 700 640 394 3500 3500 2000 3400 0 0 0 0 0 550 425 0 0 550 176 3500 0 08-Mar-99 1298 3250 3150 778 700 640 392 3500 3500 2000 3400 0 0 0 0 0 550 425 0 0 550 66 3500 0 09-Mar-99 1315 3250 3150 791 700 640 396 3500 3500 2000 3400 0 0 0 0 0 550 425 0 0 550 74 3500 0 10-Mar-99 1296 3200 3150 780 700 640 390 3500 3500 2000 3500 0 0 0 0 0 550 475 0 0 550 0 2100 0 Il-Mar-99 1320 3250 3150 792 700 640 395 3500 3500 2014 3400 0 0 0 0 0 550 425 0 0 550 0 1600 0 12-Mar-99 1310 3200 3150 787 700 640 395 3500 350~ 2000 3500 0 0 0 0 0 550 475 0 0 550 0 2100 0 I' Mar-99 1335 3200 3150 783 700 640 404 3500 3500 2000 3500 0 0 0 0 0 550 475 0 0 550 0 2100 0 · Mar-99 1327 3200 3150 781 700 640 400 3500 350C 2000 3500 0 0 0 0 0 550 475 0 0 550 0 2100 0 15-Mar-99 1330 3200 3150 782 700 640 401 3500 350~ 2000 3500 0 0 0 0 0 550 475 0 0 550 0 2100 0 16-Mar-99 1329 3200 3150 787 700 640 399 3500 350C 2000 3500 0 0 0 0 0 550 475 0 0 550 0 2100 0 17-Mar-99 1342 3200 3150 790 700 640 402 3500 350~ 2000 3500 0 0 0 0 0 550 475 0 0 550 0 1925 0 18-Mar-99 1333 3200 3150 789 700 640 399 3500 350~ 2000 3500 0 0 0 0 0 550 475 0 0 550 0 1925 0 19-Mar-99 1337 3200 3150 790 700 640 399 3500 3500 2000 3500 0 0 0 0 0 550 475 0 0 550 54 3500 0 20-Mar-99 1333 3200 3150 779 700 640 396 3500 3500 2000 3500 0 0 0 0 0 550 475 0 0 550 0 3500 0 21-Mar-99 1340 3200 3150 783 700 64( 397 3500 350~ 2000 3200 0 0 0 0 0 550 425 0 0 550 0 3500 0 22oMar-99 1358 3200 3150 793 700 640 403 3500 350~ 2000 3200 0 0 0 0 0 550 425 0 0 550 0 2800 0 23-Mar-99 1338 3200 3150 789 700 640 396 3500 350~ 2000 3200 0 0 0 0 0 550 425 0 0 550 0 1800 0 24-Mar-99 1339 3200 3150 788 700 640 396 3500 350~ 2000 3200 0 0 0 0 0 550 425 0 0 550 0 1800 0 25-Mar-99 1343 3200 3150 790 700 640 397 3500 3500 1885 3200 0 0 0 0 0 550 425 0 0 550 0 350 0 26-Mar-99 1354 3200 3150 792 700 640 400 3500 3500 1881 3200 0 0 0 0 0 550 425 0 0 550 0 650 0 27-Mar-99 1347 3200 3150 785 700 640 397 3500 350~ 1854 3200 0 0 0 0 0 550 425 0 0 550 0 640 0 28-Mar-99 1357 3200 3150 794 700 640 401 3500 350~ 1866 3200 0 0 0 0 0 550 425 0 0 550 0 600 0 29-Mar-99 1357 3200 3150 792 700 640 399 3500 350~ 1860 3200 0 0 0 0 0 550 425 0 0 550 0 525 0 30-Mar-99 1366 3200 3150 794 700 640 401 3500 350~ 1868 3200 0 0 0 0 0 550 425 0 0 550 0 475 0 31-Mar-99 1361 3200 3150 792 700 640 398 3500 350~ 1854 3200 0 0 0 0 0 550 425 0 0 550 0 475 0 TOTAL 41,204 24,421 12,290 61,021 0 0 0 798 MAXIMUM 3,250 3,175 700 640 3,500 3,500 3,500 0 0 0 550 475 0 550 3,500 0 .t~"'rERAGE 1,329 3,216 3,152 788 700 640 396 3,500 3,500 1,968 3,371 0 0 0 0 0 550 441 0 0 550 26 2,134 0 ~ 3AYS 31 31 31 31 0 0 0 6 ~.... ~/08/99 "'~, NOVEMBER DATE 01-Nov-90 02-#ov-90 03-#ov-90 04-#ov-90 05-Nov-90 · . 06-Nov-90 .. O7-Nov-90 08-Nov-90 09-Hov-90 lO-Nov-90 [ 11-Nov-90 '12-Nov-90 13-Nov-90 14-Nov-90 · 1S-Nov-90 16-Nov-90 17-Nov-90 18-Nov-90 19-Nov-90 20-Nov-90 21-g~v-90 22-Nov-90 23-Nov-90 24-Nov-90 25-Nov-90 · '26-Nov-90 27'Nov-90 28-Nov-90 29-Nov-90 30-Nov-90 t,/A T E R I N J E C T ! O N R E P O R T P L A T F O R M C C41 - 23 C24- 23 C34-23 C23-26 C41 - 26 .- INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INd ANNU INd INJ ANNU BBLS PRESS PS!G BBLS PRESS PSIG BBLS PRESS PS!G BBLS PRESS PS!G BBLS pREss PS!G 2539 3200 0 2568 3200 0 2556 3200 0 2581 3200 0 2565 3200 0 2548 3200 0 2~1 3200 0 2552 32O0 '0 2690 3200 0 2585 3200 0 2605 3200 · 2618 3200 0 2601 3200 0 2608 32OO 0 2657 3200 0 2587 32OO 0 2605 3200 '0 2636 3200 0 2623 3200 0 2595 3200 0 2601 3200 0 2625 3200 ,0 2627 3200 0 2528 3200 0 26~5 3200. 0 2598 3200 0 2654 3200 0 2652 3200 . 0 2641 32OO 0 26O9 32OO 0 1027 3500 3500 1030 3500 3525 1031 3500 3525 1036 3500 3525 1031 3500 3525 1026 3500 3500 1028 3500 3525 1011 3500 3525 1015 3500 3500 1014 3500 3500 1024 3500 3500 1035 3500 3500 1027 3500 3500 1028 3500 3500 1090 3500 3000 106~ 3500 3550 1058 3500 3550 1073 3600 3550 1070 3500 3550 1057 3500 3550 106~ 3500 3550 1076 3500 3550 1076 3500 3550 1043 3500 3550 1070 3500 3550 1048 3500 3550 1069 3500 3550 1068 3500 3550 1060 3500 3550 1039 3500 3550 SI 1250 SI 1250' SI 1250 Sl 1250 Sl 1250 SI 1250 SI 1250 Sl 1250 $! 1250 Sl 1250 SI 1250 Sl 1250 Sl 1250 SI 1250 SI 1200 Sl 1200 $I 1200 SI 1250 Sl 1200 Sl 1200 Sl 1200 SI 1200 Sl 1200 SI 1200 Sl 1200 Si 1200 Sl 1200 SI 1200 Sl 1200 SI' 1200 '96 3500 34?5 102 3500 3450 102 3500 34?5 114 3500 3425 110 35OO 3425 110 3500 3425 111 3500 3425 109 3500 3425 109 3500 3400 105 3500 3400 106 3500 3400 108 3500 3400 110 3500 34O0 108 3500 3400 129 3500 3400 '123 35OO 3410 0 3500 3410 238 3500 3400 124 3500 3410 124- 3500 3410 127 '3500 3410 123 3500 3410 128 35OO 3410 129 3500 3410 127 3500 3410 112 3500 3450 119 3500 3450 125 3500 3450 127 35OO 3450 118 3500 3450 494 3500 0 466 3500 0 453 3500 0 446 3500 0 435 3500 0 430 3500 0 424 3500 0 416 3500 0 416 35OO 0 415 3500 0 414 3500 0 413 3500 0 407 3500 0 406 3500 0 416 3500 0 409 3500 0 405 3500 0 408 3500 0 412 3500 0 406 3500 0 404 3500 0 399 3500 0 392 3500 0 371 3500 0 378 3500 0 360 3500 0 369 3500 0 380 3500 0 386 3500 0 381 3500 0 TOTAL 178,160 MAXI.HUH AVERAGE I 2605 # DAYS I 30 '12/17/90 3200 0 3200 0 31,388 3600 3550 1046 3503 3513 · 30 · 0 13,473 0 1250 3500 3475 0 0 1225 116 3500 3422 30 30 12,311 3500 410 3500 30 /7? RECEIVED.. g £0 '! 9 7990 Alaska Oij & Gas COns. t;o~;~rnJss/on Anchorage ,.. iii i i i ii i ~ i i ! ii i C23-23 C41-23 C24-23 C34-23 C23-26 C4 i-26 C44-14~D C24A-23 ACT '' 'AC~ .... ~CT ACT ACT ACT ACT AC~ INJ INJ ANNU INJ INJ ANNU: INJ INJ ANNU INJ INJ ANNU FNJ INJ ANNU INJ INJ ANNU 1NJ INJ ANNU INJ INJ 1290 3200 3110 795 700 630 438 3500 3500 2151 - 3500 '' 0 0 0 0 0 0 400 0 0 '" 550 0 i400 1249 3200 3110 751 700 630 401 3500 3500 2121 3500 0 0 0 0 0 0 400 0 0 550 366 1400 1243 3200 3110 751 700 630 399 3500 3500 2114 3500 0 0 0 0 0 0 400 0 0 550 81 1400 1243 3200 3110 750 700 630 396 3500 3500 2104 3500 0 0 0 0 0 0 400 0 0 550 21 3500 1235 3200 3110 751 700 630 394 3500 3500 2082 3500 0 0 0 0 0 0 400 0 0 550 40 3500 1245 3200 3110 751 700 630 397 3500 3500 2095 3500 0 0 0 0 0 0 400 0 0 550 24 350{) 1264 3200 3175 754 700 630 399 3500 3500 2126 3500 0 0 0 0 0 0 400 0 0 550 13 3500 1260 3200 3175 753 700 630 398 3500 3500 2119 3500 0 0 0 0 0 0 400 0 0 550 20 3500 1273 3200 3200 821 700 630 433 3500 3500 2313 3500 0 0 0 0 0 0 400 0 0 550 20 3500 1254 3200 3200 747 700 630 392 3500 3500 2094 3500 0 0 0 0 0 0 400 0 0 550 14 3500 1272 3200 3200 757 700 630 396 3500 3500 2118 3500 0 0 0 0 0 0 400 0 0 550 8 3500 1269 3200 3200 752 700 630 396 3500 3500 2106 3500 0 0 0 0 0 0 400 0 0 550 0 3500 1279 3200 3200 755 700 630 399 3500 3500 2104 3500 0 0 0 0 0 0 400 0 0 550 0 3500 1286 3200 320{3 770 700 630 399 3500 3500 2099 3500 0 0 0 0 0 0 400 0 0 550 0 3500 1272 3200 3200 793 700 630 393 3500 3500 2073 3500 0 0 0 0 0 0 400 0 0 550 0 3500 1275 3200 '3200 796 700 630 393 3500 3500 2046 3500 0 0 0 0 0 0 400 0 0 550 373 3500 1264 3250 3150 795 700 680 395 3500 3500 2091 3500 0 0 0 0 0 0 400 0 0 550 120 3500 1248 3250 3175 793 700 640 392 3500 3500 2086 ' 3500 0 0 0 0 0 0 400 0 0 550 40 3500 1262 3250 3175 799 700 640 396 3500 3500 2115 3500 0 0 0 0 0 0 400 0 0 550 12 3500 1243 3250 3175 785 700 635 395 3500 3500 2056 3500 0 0 0 0 0 ' 0 400 0 0 550 3 3500 1263 3250 3175 801 700 635 399 3500 3500 2059 3500 0 0 0 0 .0 0 400 0 0 550 0 3500 1251 3250 3175 792 700 635 399 3500 3500 1945 3500 0 0 0 0 0 0 400 0 0 550 0 2200 1250 3250 3175 795 700 635 400 3500 3500 1900 3500 0 0 0 0 0 0 400 0 0 550 0 1900 1257 3250 3175 774 700 635 402 3500 3500 1980 3500 0 0 0 0 0 0 400 0 0 550 0 1850 1240 3250 31751 780 700 635 386 3500 3500 1912 3500 0 0 0 0 0 0 400 0 0 550 0 1600 1224 3250 3175 780 700 635 367 3500 3500 1884 3500 0 0 0 0 0 0 400 0 0 550 0 1425 1233 3250 3175! .782 700 635 370 3500 3500 1881 3500 0 0 0 0 0 0 400 0 0 550 356 3500 1292 3250 3175 788 700 635 393 3500 3500 1981 3500 0 0 0 0 0 0 400 0 0 550 147 3500 35,236 21,711 ..... 11,'i17 57,755 ' 0 0' 0 1,658 3,250 3,200 700 680 3,500 3,500 3,500 0 0 0 ' 0 400 0 550 3,500 I~58 3,221 3,167 775 700 634 397 3,500 3,500 2,063 3,500 0 0 0 0 0 0 400 O' 0 · 550 59 '2,971 28 28 28 28 0 0 0 17 February-99 0 l-Feb-99 02-Feb-99 03-Feb-99 04 -Feb-99 05-Feb-99 06-Feb-99 07-Feb-99 08-Feb-99 09-Feb-99 1 O-Feb-99 1 I-Feb-99 12-Feb-99 eh-99 b-99 i ~-i-'eb-99 16-Feb-99 17-Feb-99 18-Feb-99 · 19-Feb-99 20-Feb-99 2 l-Feb-99 22-Feb-99 23-Feb-99 24-Feb-99 25-Feb-99 26-Feb-99 27-Feb-99 28-Feb-99 TOTAL IViAXIMUIVi AVFRAGE OR IGIN,4 I.c " ' STATE OF ALASKA ALA~,,~ OIL AND GAS CONSERVATION COMMIS$.,.,.~I APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend__ Operation shutdownm Re-enter suspended well Alter casing __ Repair Well X Plugging __ Time extension Stimulate Change approved program __ Pull tubing Variance __ Perforate __ Other 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 5. Type et Well: Development Exploratory Stratigraphic Service 4. Location of well at sudace At top of productive interval At effective depth At total depth Platform "C", Leg 1, Conductor 6. 541.65'N & 1596.41'W from SE corner of Sec. 23, T8N, R13W, S.M. 624.6' N & 1832' W from SE corner of Sec. 23, T8N, R13W, S.M. 669.6' N & 1907' W from SE corner of Sec. 23, T8N, R13W, S.M. 6. Datum elevation (DF or KB1 105' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well number C34-23 9. Permit number 67-51 10. APl number 50-733-20041-00 11. Field/Pool MGS/"E", "F" & "G" Pools 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner true vertical measured true vertical Length 2007' 9545' 9642 feet Plugs(measured) 9633 feet 9440 feet Junk(measured) 9432 feet Size Cemented Measured depth True vertical depth 10-3/4",40.5~,J-55 1850sx 2007' 2007' 7",23-29#, N-80 1100sx 9545' 9536' (12 Intervals) 3-1/2", 9.3#, N-80 & J-55 EUE 8rd @ 8973' Perforation depth: measured 8097-9419' true vertical 8092-9412' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Guiberson RH-1 Packers @ 8568', 8860', 8954'. RECEIVE[ AU 6 1 1991 Alaska 0ii & 6as Cons. Coral ~mchorage 13. Attachments Description summary of proposal Detailed operations program BOP sketch 14. Estimated date for commencing operation 09/01/91 '115' Oil Gas 16. If proposal was verbally approved I -- -- Service Injection Name of approver Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed V, ~, f~,~ ~ Title Division Drilling Engineer " ~ FOR COMMISSION USE ONLY Conditions of approval:I~tify commiss'~on so representative may witness Status of well classification as: Suspended Date 08/12/91 IApprov/~o. Plug integrity__ BOP Test Location clearance__ Mechanical Integrity Test_~ Subsequent form required 10- ?Ov-~. ORIGINAL SIGNED BY RUSSELL A.-Z)OIJGLASS Approved by order of the Commission ~ ORIGINAL ,SIGNED BY RUSSELL A. DOUGLASS Commissioner SUBM~ IN fRIP'LICATE Form 10-403 Rev 06/15/88 APPLICATION FOR SUNDRY APPROVALS DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL WELL NO. C34-23 REPAIR TUBING/CASING COMMUNICATION The Middle Ground Shoal well number C34-23 is currently shut-in because of a tubing leak at 13' identified via mechanical integrity logging. The well is known to have tubing/casing communication via observation of tubing/casing annulus pressure. The following operations are proposed to restore mechanical integrity in compliance with AOGCC Regulation 20 AAC 25.412 and Area Injection Order No. 9. Attached is an illustration of the current and proposed wellbore diagrams. PROPOSED OPERATIONS SUMMARY 1) Cut tubing above the top packer via wireline operations. 2) Install and test 5000 psi BOP equipment per API RP 53. 3) Kill well with Calcium Carbonate (CaCO3) mud. Estimated density is between 12.0 ppg and 15.0 ppg. 4) Pull tubing. 5) Install Baker Model "FHL" packer at ~8000' MD (above the top GN- GO perforation). Run 3-1/2" injection tubing and accessory equipment. An overshot guide will be used to ensure continuity with the downhole isolation packer assembly. 6) Displace CaCO3 mud with FIW. 7) MIT Pressure test tubing/casing annulus to 2200 psi (0.27*TVD). 8) Acid treat with 7-1/2% HC1 to remove residual CaCO3 mud via Coiled Tubing Unit. 9) Perforate or punch tubing between packers to establish communication with any additional Hemlock pay intervals. 10) Return to injection into the target injection intervals. RECEIVED AUG 1 3 1991 Alaska 0il & 6as Cons. commts~te~ Anchorage o Al IA~WG~I ], COMPLETION EQUIPMENT DETAIL SHEET MGS C3~-23 6/15/87 NO. ITEM 1. CAMCO KBM MANDREL #1 2. CAMCO KBM MANDREL #2 3. CAMCO KBM MANDREL #3 4. CAMCO KBM MANDREL #4 5. CAMCO KBM MANDREL #5 6. CAMCO KBM MANDREL #6 7. OTIS "XO" SLIDING SLEEVE 8. GUIBERSON RH-1 PACKER 9. CAMCO KBM MANDREL #7 i0. OTIS "XO" SLIDING SLEEVE 11. GUIBERSON RH-1 PACKER 12. OTIS "X" NIPPLE 13. CAMCO KBM MANDREL #8 14. CAMCO KBM MANDREL #g 15. OTIS "XO" SLIDING SLEEVE 16. GUIBERSON RH-1 PACKER 17. OTIS "X" NIPPLE 18. OTIS "q" NIPPLE (2.56"I.D. CAS ! NG APPROXIMATE TVD. MD. PSI OR , -- 2394 2394 DUMMY 4308 4309 DUMMY 5705 5707 DUMMY 6689 6693 DUMMY 7298 7302 DUMMY 8522 8528 DUMMY 8558 8564 8562 8568 8813 8819 DUMMY 8850 8856 8854 8860 8860 8866 8892 8898 DUMMY 8908 8914 DUMMY 8945 8951 8948 8954 8955 8961 8967 8973 10 3/4", 40.5#, J-55 @ 2007' w/1850 sx 7" 23-29#, N-80 @ 9545' w/llO0 sx PBTD = 9419' TD = 9642' TUBING s . 3~ 1/~", 9..?~, N-~o ~ J-55 EU~ ~o e 8973' 7 " '' PERFORATED ZONE GROS~ INTERVAL , g - '>7 GN-GO 8097-809g' GN-GO 8106-8114 lO GR-GS 8407-8439 11 HC-HD 8698-8728 12 HE-HF 8799-8844 13 HI-HK 8908-8932 14 HI-HK 8939-8949 ~ 15 HK-HN 8966-9088 16 HN-HR 9103-9164 HN-HR 9172-9250 17 = 18 HR-HZ 9268-9278 ~ HR-HZ 9294-9419 L RECEIVED AUG 1 ) 1991 Alaska Oil & Gas Cons. Comm~ssten Anchorage ATTACHMENT III C34-23 PROPOSED STATUS REPAIR TBG/CSG COMMUNICATION TOC lit SURFACE 3-1/2' 9.8# L-80 EUE 8rd TBG at 8080' with MODIFIED COUPLING8 3-1/2' 9.8# N-80 & J-56 TBO from 8050' - 8973' 'G' 8AND PERFORATIONS: ON-OO 8097' - 8099' GN-OO 8106' - 8114' OR-G8 8407' - 8489' HEMLOCK PERFORATIONS: HC-HD 8698' - 8727' HE-HF 8799' - 8844' WAId/C8423P PS.CH T HI-HK 8908' - 8982' HI-HK 8989' - 8949' HK-HN 8966' - 9088' HN-HR 9108' - 9164' HN-HR 9172' - 9250' HR-HZ 9268' - 9278' HR-HZ 9294' - 9419' PBTD at 9419' OTI8 'X' NIPPLE at 800' 24' CONDUCTOR at 370' 0-200/" 40.5# J-66 CEMENTED w/1850 ex 'G' INCLUDINO TWO TOP JOB8 TOC (CBL) at 6080' */- OTIS 'X' NIPPLE at 7966' 16' PBR at 7985' BAKER 'FHL° RETRIE~P, BLE PACKER at 7986' OTI$ 'X° NIPPLE at 8020' BAKER 8BR SKIRT at 8050' GUIBERSON RH-1 PACKER at 8568' OUIBER$ON RH-1 PACKER at 8860' OUIBERSON RH-1 PACKER at 8964' EOT at 8978' 7' PRODUCTION CASING at 9645' 0 - 124' 29# N-80 124' - 7468' 26# N-80 7468' - 9646' 29# N-80 RECEIVED AUG 1 5 t991 Ala$~.Oil & Sas Cons. CommtSslen Anchorage Shell Western E&P In=O 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 August 12, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' SUBJECT' RETRACTION OF APPLICATION TO SUSPEND MGS C34-23 SUBMIT APPLICATION TO REPAIR WELL Further to our August 6, 1991 telephone discussion with Blair Wondzell of your staff, we are hereby retracting our submission of application for Sundry Approval to suspend Middle Ground Shoal Well No. C34-23 dated July 24, 1991. The stringent requirement of cement squeezing the Hemlock intervals would effectively eliminate the option of using the well for future Hemlock injection. After further review, and in consideration of mechanical problems experienced during a workover on the offset injector C24-23, we are submitting an application for sundry approval to repair the tubing/casing communication and return the well to injection. If you have any questions regarding the application or supporting documents, please contact Paul Huckabee at (907) 263-9646 or Bill Miller at (907) 263-9633. Very Truly Yours, Vo F. Division Drilling/Production Engineer Alaska Division VEU/PTH/wam Enclosures RECEIVED AUEi 1 1991 Alaska Oil & Gas Cons. Commissten ;Anchorage July 17, 1990 Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 Mr. Mike Minder Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Minder: SUBJECT: RADIOACTIVE TRACER suRvEYS (RTS) AT MIDDLE GROUND SHOAL FIELD I GEOL ASgTt '-~EOL AsSTI STAT TECH I'" This letter is in response to your telephone conversation with Susan Brown-Maunder of Shell Western E&P Inc. on July 5, 1990. During this conversation you requested the following: 1. Data to verify the tubing leak observed at 13' in the C34~23. 2. Verification of which wells have tubing/casing communication. 3... Justification of why the RTS's a~e the preferred method over pressure testing in Al1-12 and A11-13RD2. The tubing leak at 13' in C34-23 was identified by ejecting Radioactive (RA) material under shut-in conditions and observing fluid movement in the tubing. RA material was ejected twice (at depths of 200' and 130') and the Gamma Ray detectors were moved uphole to monitor the fluid movement. In both cases, the upward fluid movement ceased at a depth of 13'. We there- fore conclude that a leak is present in the tubing at a depth of 13' No "raw" data was acquired to verify the fluid movement, however, the ~RE- MARKS" section of the "R/A TRACER SURVEY" log (submitted to your office via cover letter dated June 15, 1990) documents the observation of the leak. A copy of the "REMARKS" section is attached for your convenience. All three of the subject wells referred to in the June 15, 1990 letter have tubing/casing communication. Again, the three wells are C23-26, C24-23, and C34-23. As stated in the June 15, 1990 letter, the communications are known to exist via tubing/casing annulus pressure observations. Attached for your convenience is a copy of the May 1990 AOGCC form 10-406 showing equalized pressures on the tubing and casing. We therefore conclude that these three wells have tubing/casing communication. In addition to these three wells on Platform "C", one well on Platform "A" has elevated pressure on the tubing/casing annulus. The well, A12-12, is currently injecting 602 BWPD at 3500 psi. The annulus pressure averaged 2614 for the month of June. Since the tubing and casing pressures are not equalized, it is not clear whether the tubing and casing are in communication. ARTS survey run in June 1990 indicates no fluid leaving the tubing above the top ~'~'~....~ii]~r~"~V~D PTH/071390. The RTS method of demonstrating mechanical integrity on wells Al1-12 and All-13RD2 was requested in compliance with Rule 6 of the Area Injection Order {AIO) No. 9 amended September 26, 1988. The objective of the RTS method is to demonstrate no fluid movement behind tubing above the top packer. This objective is consistent with conditions stated in AOGCC Approval No. 630 {dated 12/19/86) for the RTS survey on C24-23. In general, the RTS method is preferred at Middle Ground Shoal (MGS) over pressure testing because of the age of many of our injection wells {for example, the Al1-12 wellbore is 24 years old). Exposing the casing to the test pressures required increases the risk of casing damage. The RTS procedure will identify any significant water injection above the top packer. Also, as noted in Finding No. 4 of the AIO No. g, the MGS aquifers are exempt from the Underground Source of Drinking Water protection by .both the EPA and AOGCC. In consideration of our "exempt" status, we request "Administrative Relief" from tbe annulus pressure test requirement. Sincerely, R. G. Blackburn Manager Alaska Operations PTH/SBBM/ts CC: C. M. Kidwell - WCK 1178 W. F. Simpson - Anchorage R. G. Lippincott - WCK 1140 V. E. Unger - Anchorage B. N. Osborn - Kenai PTH/071390. PIIID LOOATJ0~d WILL 0orfOAmY KLq~d COHO. e, S4F # a l~e' W ~ C84-~8 Tho wel name, Iooatlon arid borohola reforence data wore fufl~hod by tho oultomor. A1 ImorprotatJonl are opinions baled on Iflforenco$ from eJoutrk~al or 0thor moalme~nenta end we cannot, end do not guarsmee the acQuracy or eoffoQtnen of any k~torlxetldonl, end we Ihll not, exoeot In tho eon of grog or wJlfd rsoolgenco on our Imrt, b~ IiobJo or roaponoible for any lose, anita, dlmoge8 or oxpenooo incurred or sustained by oflyono rosultlng from any intoq~rotatkma mado. b_y any of.? o.J. flonra, aOont8 or empJoyfla. Thole ifltofl)rotallonl are aim lubJ~t0 Clluoo 4 of OUr (bi~orll T0ff~8 IIld G0J~l~HXla ia Mt out In our current Pdo0 Sehedult NO. 0NE BefvJOO ~dor NO. Speed , DATA Tool Numberl TM ToOl Number2 ToOl Number 8 TO44 Mt)er 4 ;GTR TO~I ~ 8 ATT-B TO~ Nsm14)~ O C~L-U PTS-A 2~4 'rET REMARKSt DPERATDRSt ROY DRUCKS, TRDY PABST CEHTRALIZERS RUM ADDVE TRACER L FLDNMETER TDDLS. NELL NAS SHUT Zfl APPRDX. 8 HRS DEFDRE RXH, HELL HAS RESTRDXLXZED 9 HRS PRXDR TO LDGGZMG. IMJECTXDH RATE DURIHG LDGGZHG AVERAGED ADDUT 1100 ~PD. IHJECTIDM PRDFILE/FALLDFF UHDER SEPARATE HEADER. TRACER VELDCITY SHDT DEPTHS SPECIFIED JY CUSTDMER. DEPTH REFEREHCE FDR TRACER SHDTS NAS GRSG MEASURE PDIMT. 90# SPACIHG JETHEEH TRACER GAMMA RAYS. SEE TRACER SHDT FILES FDA TIME SCALE PER DIVISIDH. PRESSURE SEHSQR e 9260' FDR 6 1/2 HR FALLDFF TEST. PRESSURE SURGIHG ADDUT 10 PSI DURIMG EMTIRE SHUT-IH PERIDD. A FIHAL YELDCXTY SHDT fiRS MADE AFTER*THE AFTER SHUT-IH PASS. THE TRACER DID HDT MDVE DDHHHDLE~ SD NE MADE A DRAG PASS UPHDLE TD FIHD THE SLUG. HE FDUMD THAT THE SLUG HAD MIGRATED UP TQ t3'~ AND MUMERDUS PASSES HERE MADE TD VERIFY THAT IT DIDM*T MDVE FURTHER, THAMK YDU FDR CALLIMG SCHLUMDERGER! SHELL WESTERN E&P INC. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COHHISSIOH MONTHLY INJECTION REPORT 2O AAC 25.432 MIDDLE GROUND SHOAL NAY, 1~90 Nam of Operator Field and Pool Month and Year of Injection DALLY AVERAGE TOTAL MONTHLY TUBING PRESSURE 1. 2. 3. 4. 5. 6. ~. Well # API# Class Field & Days in MAX Average 50- Pool Code Operation PSIG PSIG CASING PRESSURE 8o 9. MAX Average PSIG PSIG A 11-12 733-10083-00 W 524114 31 3500 3500 100 9 INJECTION INJECTION 10. 11. 12. 13. Liquid Gas Liquid Gas (BBL) (MCF) (BBL) (MCF) 691 20989 A 11-13 733-20007-01 W 524114 31 3500 3500 A 12-12 733-20044-00 W 524114 31 3500 3500 A 23-01 733-20238-00 W 524114 31 3500 3500 A 33-14 733-20057-00 W 524114 31 3500 3500 A 34-11 733-10084-01 W 524114 Sl 0 0 A 34-14 733-10086-01 W 524114 31 3500 3500 A 44-1i 733-20027-00 W 524114 Sl SI C 23-26 733-20071-00 W 524114 31 3700 3700 C 24-23 7'53-20145-01 W 524114 31 3500 3500 C 33-26 733-20125-00 W 524114 Si S] SI C 34-23 733-20041-00 W 524114 31 3500 3500 C 41-23 733-20163-00 W 524114 31 3200 3200 C 41-26 733-20409-01 W 524114 7 3700 3700 C-Line 733-20174-00 W 524114 Si Si SI hereby certify that the foregoing is true and correct to the best of my knoutedge. 100 20 527 16122 2800 2732 642 19628 0 0 1240 37926 0 .0 1456 44522 55 ,28 1 1 22 18 855 25875 60 27 0 0 3680 3643 143 4419 3600 3519 957 29672 0 0 0 0 3650 3497 1101 34141 0 0 2631 81561 0 0 4 28 620 516 0 0 Total 314884 Title Manager Alaska Operations, Alaska Division Date June 12, 1990 Form 10-406 Rev. 12-1-85 Submit in DupLicate \LOTUS\HTHLYINJ\NAY-RPT.~K1 June 18, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive' Anchorage, Alaska 99501 Gentlemen- Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 ~SR EN~3 SUBJECT' NOTiFICATiON OF CESSATION OF INJECTION INTO MIDDLE GROUND SHOAL WELL C34-23. By way of this letter Shell Western E & P Inc. is notifying the Commission of our decision to cease injecting into the MGS well C34- 23. The well was "shut-in" on June 13, 1990. The decision to "shut- in" the well was based on interpretation of the radioactive tracer survey which showed that there is a tubing leak at approximately 13' below the wellhead. C34-23 will not be used again until a workover can be scheduled to correct the tubing leak. SWEPI is estimating that workover operations can commence late in 1991, which is the anticipated conclusion of the current Platform C drilling schedule. If you have any questions regarding this matter, please contact either Paul Huckabee or Susan Brown-Maunder at 907/263-9646 or 907/263-9613, respectively. Very Truly Yours, Manager Alaska Operations Alaska Division RGB/vj RECEIVED JUN t 0 1990 Alaska Oil & Gas Cons. Commission Anchorage \LETTERS\AOGCC\061890. DOC Shell Western E&P Inc. O 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 June 11, 1990 Alaska Oil and Gas Conservation Commission ATTN: Elaine Johnson 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: TRANSMITTAL OF REQUESTED INFORMATION REGARDING THE SWEPI OPERATED MIDDLE GROUND SHOAL FIELD Dear Ms. Johnson' In a recent telephone conversation you discussed with Ms. Susan Brown-Maunder information that would be helpful to you if we could provide it. Enclosed, for your convenience and use, are the following: 2 location surveys showing the location of Platform A 1 list of conductor/well locations (in relation to the SE corner of Sec. 11, TSN, R13W) for Platform A wells 1 location survey showing the location of Platform C 1 list of conductor/well locations (in relation to the SE corner of Sec. 23, T8N, R13W) for Platform C wells In addition you requested a revised copy of the Well Completion or Recompletion 'Report and Log (10-407) for the recently completed well C21-23. The well location at the top of the producing interval and the well location at total depth as been changed to reflect the actual surveyed location. If you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at (907) 263-9613. Very TrulyfYours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc: Susan Elsenbast-AOGCC \LETTERS\AOGCC\061190. DOC RECEIVED Anchora~ PLATFORM "C" MIDDLE GROUND SHOAL CONDUCTOR/WELL SURFACE LOCATIONS LEG 1 Centered 541.65 ft. North and 1596.41 ft. of the SE Corner of Sec. 23, TSN, R13W, SM. DISTANCE FROM ~ SE CORNER CONDUCTOR WELL NORTH WEST 1 C23-23 547.10 1599.00 2 C32-23 547.25 1594.46 3 C34-26 544.25 1591.06 4 C24-26RD 540.57 1590.68 5 C31-26 536.91 1593.01 6 C34-23 535.88 1597.22 7 C23-26 538.03 1600.98 8 C22-26RD 542.18 1602.22 LEG 2 CONDUCTOR 9 10 11 12 13 14 15 16 LEG 3 LEG 4 CONDUCTOR 25 26 27 28 29 30 31 32 Centered 618.65 ft. North and 1549.76 ft. of the SE Corner of Sec. 23, TSN, R13W, SM. WELL DISTANCE FROM SE CORNER NORTH WEST C2 C2 C4 C4 C2 C2 C2 C1 2-23 623.65 1552.66 4A-14 624.15 1548.36 3-14 622.65 1544.76 1-26 618.25 1543.86 1-23 613.85 ~1546.26 1-26 612.65 1550.46 4A-23 614.85 1554.26 3-23 619.15 1555.66 Centered of the SE Centered of the SE 582.42 ft. North and 1489.90 ft. Corner of Sec. 23, TSN, R13W, SM. 505.41 ft. North and 1536.56 ft. Corner of Sec. 23, TSN, R13W, SM. WELL DISTANCE FROM SE CORNER NORTH WEST C42-23 C31-23 C43-23 C41-23 C33-26 C-LINE C44-14RD C24-23 509.00 1541.00 509.81 1536.57 507.65 1532.61 503.51 1531.56 499.00 1534.44 498.37 1538.72 500.87 1542.26 505.12 1543.10 West West West West DISTANCE FROM CENTER OF LEG N/S E/W 5.45 -2.59 5.60 1.95 2.60 5.35 -1.08 5.73 -4.74 3.40 -5.77 -0.81 -3.62 -4.57 0.53 -5.81 DISTANCE FROM CENTER OF LEG N/S E/W 5.00 -2.90 5.50 1.40 4.00 5.00 -0.40 5.90 -4.80 3.50 -6.00 -0.70 -3.80 -4.50 0.50 -5.90 DISTANCE FROM CENTER OF LEG N/S E/W 3.59 -4.44 4.40 -0.01 2.24 3.95 -1.90 5.00 -6.41 2.12 -7.04 -2.16 -4.54 -5.70 -0.29 -6.54 · · J. ddl[ M · L0~AT ION COOK lid L.ET' ,"-' ALASKA SCJLC I', 2000' lldlr~k IN? ,t ' · . !' May 5, 1989 Alaska Oil & Gas Conservati°n Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Shell Western E&P Inc. 601 West Fifth Avenue- Suite 810. ~1' /~_-.~._-!'~----'~~ Anchorage, Alaska 99501 I //7 - [ -- Gentlemen: SUBJECT: AREA INJECT,ION ORDER NO. 9 (CENTRAL PORT[ON MIDDLE GROUND Stl~lAL FIELD), RULE 6 As part of the requirements of Area Injection Order (AID) No. 9, Rule 6, a schedule for performing radioactive tracer surveys (RTS) must be submitted to and approved by the commission. During conversations with members of your staff it was indicated that the Commission may accept recent RTS's even though the commission representatives did not have the opportunity to witness the surveys. By way of this letter, SWEPI is submitting our schedule for performing RTS's on injection wells and request that you accept the recent surveys as satisfying the requirements of Rule 6 based on the enclosed RTS logs. (See Attachment 1 for list of enclosed logs.) Attachment 2 is a table showing the mechanical integrity history for the MGS in,iection wells. Also shown is the proposed testing schedule noting those wells for which we' are asking your acceptance of the previously run surveys. Your early review of this proposal would be greatly appreciated. If we can be of further assistance, please do not hesitate to call Ms. Susan Brown-Maunder at (907) 263-9613. Very truly yours, W. F. Simpson Manager Regulatory Affairs SBBM/hr Enclosures t~s~ O~t & r~s ConS. Com~tsslon GTK1/050489 Attachment 1 LIST OF ENCLOSED LOGS Wel 1 No. ~ AIl-12 ~, Al1-13 RD II t A12-12 u A33-14 v, A34_14 RD II ~ A44-11 ' C23-26 ~ C24-23 ~ C34-23 V' ~ C41-23 Log(s) RAT - 6/17/87 NFL - 1/17/86 NTL - 3/4/88 NFL - 3/5/88 RAT - 6/17/87 NFL - 9/5/86 RTS - 3/26/88 NFL - 1/26/87 NFL - 2/12/87 NFL - 1/27/87 NFL. 2/10/87 NFL - 2/12/87 NFL - 10/24/87 GTK1/050489 RE RETAIN THIS SECTIONJ=OR-YOUR.,RECORDS .............. ~COMP, NFL-TEMP, OF., 2/lO& 12~.~-1 C23-26 (NFL), C24-23 (NFL) w.~'NFL~~'/~7/87~ PRINTS NEG. SEPIA 1 PRINTS 0 NEG. 1 SEPIA PRINTS NEG. SEPIA PRINTS NEG. SEPIA PRINTS ~ NEG. SEPIA PRINTS ~ NEG. ~ SEPIA NEG. PRINTS..=_ S.~,PlA ABOVE RECEIVED FROM: DRES ATTENTION JOHN BOYLE ~~I~Al~~%~ ~ SIGNED Alaska Oil aD~'~E Cot~s. Commissiot19. Anchorage ALL PLS'$ '~",,, STATE OF ALASKA ALASK -')IL AND GAS CONSERVATION COMN"~,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 3. Address 601 West Fifth Avenue, Suite 810, Anchorage, Alaska 99501 4. Location of well at surface Platform "C",' Leg 1, CondOr 6 @ 5.77'S & 0.81'W from center Leg1 @ 541.65'N & 1596.41'W from SE corner of Sec. 23, 5. Datum elevation (DF or KB) 105' DF 6. Unit or Property name Middle (~round ~ 7. Well number C 34-23 g~,_P~r{nit number 9. APl number 5O-- 733-20041-00 10. Pool At top of productive interval 1BN, R13W, 5.M. 2.72'N & 8.86'W of surface location At effective depth At total depth 15.00'N & 23. IO'W of surface location feet~ ~,~ 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate 2007 ' Production 9545 ' Liner Perforation depth: measured true vertical 9642' 9633' 9419' 9411' feet feet feet feet Plugs (measured) Junk (measured) Size Cemented 10-3/4", 40.5#, J-55 7", 26 & 29#, N-80 Measured depth 1850 sx 1.100 sx 8097-9419 ' 8092-9412' (12 intervals) @ 8360' Tubing (size, grade and measured depth) 3-1/2", , Packers and SSSV (type and measured depth) packer set @ 7127' True Vertical depth 2007' 9545 ' D ZC 1 2 198G Alaska Oil & Gas Gons. Commission Anclmrage 12.Attachments Description summary of proposal Fi( Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ' Title Product i on Superintendent Date 12/8/86 Commission Use Only Conditions of approval Notify commission so representative may witness i [] Plug integrity [] BOP Test [] Location clearance RAT tests to be run in 1987 to demonstrate no fluid movement behind tubing above the top packer; at least one shot (in each well) to demonstrate ability to see fluid movement behind tubinm. ...... :~ ~.., .... ~.~ c-~.~,.~ by order of Approved by '~:( :< :~';~:~ ~:~}~'~-: '~:~ ~;~,u~m~¢ ~°mm~ssioner the commission Date/~ ..... ~-~:~: ~ ~ Submit in triplicate Form 10-403 Rev 124-85 ATTACHMENT TO APPLICATION FOR SUNDRY APPROVAL This Application for Sundry Approval is being submitted to present to the Commission Shell Western E&P Inc.'s surveillance plan to insure integrity of wells which indicate communication between the tubing and the tubing/casing annulus by elevated pressure in the annulus. The surveillance plan will use periodic (two to three year cycle) radioactive tracer surveys to determine if there is any fluid movement behind the tubing above the packer in the tubing/casing annulus. Between surveys annulus pressure and injection flowrate will be monitored. These values are reported to the Commission monthly. If, for unexplainable reasons, the flowrate increases by 25% or more, or the annulus pressure increases by 200 pounds or more, a radioactive tracer survey will be run to determine if there is flow in the annulus. This procedure will insure that no significant amount of water is injected outside of the waterflood interval. As all aquifers beneath the Middle Ground Shoal field are exempt aquifers, there is no threat to drinking water in the unlikely chance that an injection water leak should occur. D ;:_'C 1 2 1.986 Alaska 0il & G'3s 6ons. (;omm!ssion Anchorage 1211/MISC SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited ', HOUSTON. TEXAS 77001 ,.-E^.,r .=,,-y ,'o SEPTEMBER '19,1985 500 W.? 'P."/CAheFS I'CE%? ?ORT RD. ANCHORAGE, ALASKA 99518 " ATTN: BETH CUZZORT SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON, TX. 77001 Affention: LOG FILES, WCK 4147 Gentlemen: Enclosed are 1BL prints of the PRODUCTION LOG Company SHELL WESTERN F2~P INC. , Well MGS C 34-23 Field MIDDLE GROUND SHOAL ., Count7 KENAI State ALASKA on: , Additional prints are being sent to: 1BL nrints SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON~ TX, 77001 ATTN' R.J.VALLEJO,,WCK 1134 1RFOI~--SEPtA ~ATE' OF..'~LASKA" ~ . ALASKAOIL & GAS CONSERVA~ON CONN. [3001 PORCUPINE DR. ~'~ k~NCHORAGE, ALASKA~50X HoW _ -' 2BL nrintS SHELL WESTERN E&P INC. 60! W.F!FTH AVE;SUITE 810 ANCHORAGE~ ALASKA 99501 ATTN: JOE FRAM _ 1MYLAR 1BL nrints ARCO ALASKA INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99501 ATTN' JOHN C. HAVARD 1BL nrints SHELL' PLATFORM "A" OR "C" ~,.S'HELL KENAI OFFICE NORTH STAR ROUTE P.O. BOX 485 WIK RD. KENAI, ALASKA 99611 ~prints 1RROLLED SEPIA ~r~s U.m.A. ,INC. P.O. BOX 107839 ANCHORAGE, -ALASKA 99510 ATTN: J.L. WEAVER prints SOS--1565-A The film is RETURNED TO SHELL (HOUSTON) We appreciate the privilege of serving you. RECEIVED BY Very truly yours, SCHLUMBERGER OFFSHOR ~ C°mmission DISTRICT MANAGER November 3, 1983 Shell Oil Company 200 North Dairy Ashford P. O. Box 527 Houston, TX 77001 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: Attached are duplicate copies of the Monthly Report of Drilling and Workover Operations for Shell's Middle Ground Shoal Well A12A-1 and Seal Island Well No. BF-47. Also attached are duplicate copies of Subsequent Sundry Notices for Workover Operations for Shell's MGS Wells C31-23, , C31-26 and C24-23. Yours very truly, R. G. Hollis Manager Production Administration Pacific Frontier Division RGH'mh Attachment 4nChora,. ' Oorar,,~ ~e ~#t$8100 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator . 7. Permit No. Shel 1 Oil Company : 67-51 3. Address 8. APl Number John Douglas, P.O. Box 4500, Kenai, AK 99611 5o_733-22041-00 4. Location of Well 9. Unit or Lease Name HGS OTHER [] CondUctor 6, Leg 1, 5.77' S & 0.81' W from Center Leg I which is at 541.65' N & 1596.41' W from SE COrner of Sec 23, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 106' D.F. 12. I 6 . Lease Designation and Serial No. ADL 18756 10. Well Number C 34-23 11. Field and Pool Middle Ground Shoal Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation X~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). PROPOSAL' AcidiZe with Coiled Tubing. 10/22/83 - RU and pressure tested Dowell and Otis to 5000 ~sig. RIH & pumped filtered sea water to 9419'. Pumped 600 gal 10% HCL across perfs from 9419'-8966' ½ bbl/min @ 4500 psig. Pumped 2100 gal HCL/HF 7½-1½% @ 4500 psig across perfs. Pumped 600 gal 10% HCL across perfs. Displaced coiled tubing with i12' bbls filtered sea water. POOH & Rigged down. RTI._.~.~._~ 14. I hereby ~et'~ify that tile/re.o, pi~g true and correct to the best of my knowledge. Signed v - Title The space below for Commission use Production Adm. Manager 11/3/83 Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate /-'" STATE OF ALASKA ALASKA (alL AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL PXlX 7. Permit No. 67-51 OTHER [] 2. Name of Operator Shell Qil Company 3. Address 8. APl Number dohn Douglas, P.O. Box 4500, Kenai, AK 99611 5o- 733-22041-00 9. Unit or Lease Name MGS 4. Location of Well Conductor 6, Leg 1, 5.77' S & 0.81' W from Center of Leg 1 @ 541.65' N and 1596.41' W from SE Corner of Sec. T8N, R13W. S.M. 5. Elevation in feet (indicate KB, DF, etc.) 106' D.F. 6. Lease Designation and Serial No. ADL 18756 23, 10. Well Number C 34-23 11. Field and Pool Middle Ground Shoal 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of Starting any proposed work, for Abandonment see 20 AAC 25.105-170). Proposal' Determine injection profile. 10/15/83 - Rigged up Dresser Atlas Ran spinner survey. 10/16/83 - Ran radioactive tracer injection survey. R.D. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space belo~ for Commission use Conditions of Approval, if any: Date 10/27/83 By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate r--,. STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Shell Oil Company, 3. Address John Douglas, P.O. Box 4500, Kenai, AK' 99611 4. Location of Well Conductor 6, Leg 1, 5,77~'' South and 0.81t'~est from Center Leg'l which_is at 541.65'2 North and 1596..41t' West from Southeast Corner of Sec. 23, T8N, R13W, S,M? 5. Elevation in feet (indicate KB, DF, etc.) 106t' D.F. 12. 6. Lease Designation and Serial No. 7. Permit No. 67-51 8. APl Number 50- 733-22041-00 9. Unit or Lease Name MGS 10. Well Number C 34-243 11. Field and Pool Middle Ground Shoal ADL 18756 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Please See Attached A!aska 0it & Gas Cuns~ Cornmis:sior; Anchorage 14. I hereby certi, f4, that the foCegoing is true and correct to the best of my knowledge. Signed/~~ .~ Title Mgr, Prod. Admn. The space below for Commission use Date, 9/30/83 Conditions of Approval, if any: ORIG:NAL SIGNED BY LONNIE I;. SMITB Approved by Approved Copy - Returned-- By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate .A~.~TUORITY FOR EXPENDITU~''~ ' ' '1~. 8RANC~'OFFIC~ ORIGINATING OFFICE ~,F.F. NO. ,-' PRODUCTION IPACIFIC DIVISION HOUSTON I,OCATICiN OF I:~IOJECT AlqqqOPRIATION NO. P1 atform "C" 8/24/831 Middle Ground Shoal Field ~r. Kenai, AK WORK SMELL'S 33 % SNARE ORDER TYPE DE$CRIFTION ,, NUMBER 100~ COST aU~ET NON. BUO~ET E;XI~J~IS~ TOTAl. i i R&R Acidize C34-23 132,000 $10,700 $10,700 using coiled tubing Non Operators Approval Not Required Requested by- J. ti. Douglas T. S. Burns Su.-~o?^~ $32,000 $10,700 $10,700 -.. i BUDGET' AVAILABLr IN BUDGET RETIREMENT EXPENSE POSITION .... NEW CAPITAL FUNDS REQUIR(O BY BUDGET REVISION TOTAl. COST ~ $1 0,700 .... I ' I J USTI F I CA, TI ON: ........ See Attached Justification · , Alaska 0it & Gas 6',' Anchoraga ['-] OV(R ...... - - i FIECOMMENDED APPROVALS . .. . Justification Acidize with Coiled Tubing C34-23 Middle Ground Shoal Field Funds totalling $32,000 ($10,700 Shell's 1/3 share) are requested to acidize C34-23, Platform "C", Middle Ground Shoal Field, Cook Inlet, Alaska. The economics are as follows' Shel 1 Net Total Gross Expenditure $10,700 $32,000 Injection Increase BDW 66 200 Oil Response BDO 8.3 25 P.V.P.A.T. @ 14% 12,981 38,943 % P.V.P.A.T. 122 122 Pay Out 5 5 Well C34-23 was drilled and completed in October 1967. In 1969, well C34-23 was converted to injection with an initial rate of 4500 BDW. In 1970, the well was pulled and the HI/HK was isolated with packers. After declining to 1600 BDW in 1982, the well was acidized using coiled tubing. A total of 2800 gallons of HC1 and mud acid was placed across the HK/HZ perforations. Injection increased to 1900 BDW for 8 months as a result of the acid job. The injection rate has since declined to a rate of 1700 BDW. The northerly offset producer (C43-23) was recently reperforated (Dec. '1982) in the HK/HN(L). Oil production increased approximately 300 BDO, but declined at 55% per year. Subsequent acid and reperforating jobs proved uneffective. It appears that the HK/HN(L) zone lacks pressure support in this area. Stimulation of C34-23 in this zone would improve the situation. In August 1983, C43-23 had further water breakthrough in one ot its producing members. Injection surveys are planned in the offset injectors to possibly determine which well contributed to the breakthrough. Acidizing C34-23 is contingent on they results of the survey. Both C24-23 and C23-26 were acidized along with C34-23 in the sprin9 1982 program. Initial injection increase from the program was 2650, ut quickly' stabilized at an increase of 1800 BDW. Four producers in Pattern 5 and 6 responded to the increased injection. In oil increase of 240 BDO over the previous decline was noted. An 8 to I ratio of incremental injection to production was established. Since August, 1982, Platform "C" has experienced a fuel gas shortage. Frequent water flood shutdowns have occurred as a result of the fuel gas shortage. During the shutdown periods, the conditions were favorable for bacteria growth in the water injector's wellbore. It is believed that a combination of bacteria and scale have clogged the perforations resulting in the decline in injection. An acid treatment will kill and dissolve the bacteria along with dissolving scale and clay fines. If this treatment is successful, a study will be undertaken to determine the extent of bacteria perforation plugging and the feasibility of a continuous biocide injection system to eliminate bacteria growth in the wellbore. Acidizing C34-23 in the lower zones should increase the injection rate back to the 1900 BDW. This 200 BDW increase in injection should increase production in the neighboring wells by 25 BDO. The increase is assumed to have a 50%/year decline rate over a 12-month period. Your approval is recommend. TSB 'mh Prognosis Acidize with Coiled Tubing C34-23 W. H. Room #1 Conductor 6 Middle Ground Shoal Field Status- Objective' Procedure- 1. e e Well currently injection 1700 BDW at 3500 psi. Increase injection by removing scale and bacteria which may have formed in the last 18 months. Rig up wireline and test lubricator to 3000 psi. Make drift run to bottom. Tag and record bottom. P.O.O.H. and rig down. Rig up coiled tubing and acidizing equipment. Test acid according to attached quality control procedure. Filter all fluids on the fly through a 2 micron filter. Test all lines and coiled tubing to 5000 psi. With well shut in, R.I.H. with coiled tubing to 9419' while pumping inlet injection water. With coiled tubing at 9419', pump the fol 1 owing treatments: Stage Acid I 10% HC1 2 12%-10% HC1-HF 3 10% HC1 4, V o 1 ume 700 gal. (17 Bbls) 2100 gal. (50 Bbls) 700 gal. (17 Bbls) (Acid additives are listed on attached information sheet) Reciprocate pipe across perforated interval (9419'-8966') during each stage of acid treatment. Displace acid to end of coiled tubing using filtered injection water. Pump an additional 10 Bbls injection water to flush coil. P.O.O.H. with coiled tubing. ~, 5~ Place well equ i pment · on injection. Rig down coiled tubing Send results to T. S. Burns, Houston. and acid Appro~ Date_~ Coiled Tubing Specifications Working Depth (1.255 S.F.) Max. Working Pressure Tensile Strength Tubing O.D. Tubing I.D. Wall Thickness Capacity Tubing Weight 16,500' 5,000 psi 15,300 lbs 1.00 in. 0.850 in. 0.075 in. 0.702 bbls/lO00 ft. 29.48 gal/lO00 ft. 0.63 lbs/ft. Cost Estimate C34-23 Coiled Tubing Acidization le 2. 3. 4. 5. 6. 7. 8. 10. 1400 gal 10% HC1 2100 gal 10% -12% HC1-HF Acid Additives Pump 1.5 days @ $1,300/day Tanks 1.5 days Lines 1.5 days Personnel 1.5 days Coiled Tubing @ $5000/day Miscellaneous Total Add 10% Contingencies Say 1,400 4,600 1,500 3,000 1,200 2,500 5,500 7,500 2,000 $29,200 $32,000 Acid Additives Composition 10% HC1 (Hydroch 1 ori c Ac i d) 0.3% W-35 (antisl udge) 0.4% F-75N (surfactant) 14 lbs/lO00 gal L-41 1.2% A-200 (inhibitor) 12% - 10% HCl-HF (Mud Acid) 0.4% W-35 0.4% F-75N 14 lbs/lO00 gal L-41 1.2% A-200 biO BALL VkLVE N~PLE /~s o,~""~tobar, i1~ 1970 ', /'.. !' :.. · . . ' .:'.'.. .,. :'%:..,,, ... . . ALI, DEPTHS ARE MD o , K~ #1 @.2.,'39k' ." " · . , · : ,., , .o~..j,''. ~:,..,... ....'. ;..' · .- , . . . ... .., , ' ~ ,,. · .. .. · . ,. · · , , -. . . . , :. ,. . . , · · . . · , ., . · .. , ,.. .... . ,' · · .. , , , · KB~//5 ~ fi,?o?' .,. :'.'.. ..: . . . .. .- ., · -., ',,'. ....'., '. , · , ., ,, , : ,, . .... , '. ,, ..... , ,. · .. . ,. ,. . . . . . . .. ,. . ,. . . . . , . '. ~..j, '.,. . . . , -2. . . , : PACKER XO SL~WE @ 8,, RH-1 PACKER @ 8~860' X-NIPPLE @ 8~866' //~ e XO SLEkYE ~ 8 ~ / o~-~.,'~'''''?' 1 ,[,?, : / ,~,,-,, , I ADL II75& : ~ ~z-~ ~ ~. , ~ / / ~ .,. ~ ~ / .t · , t ~ ~ ' ~ / ~ . / ~ PRODUCING W~L_ : //~2 ~L~' ~ / ~P.~ PLUGGED & ABND. ~ , i;;~~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL Injector 2. Name of Operator Shell 0ill Company' 3. Address John',Douglas, P:0.. Box 4500, Kenai, AK 99611 4. Location of Well Conductor 6, Leg 1, 5.77~, S & 0.81'.' W' from Center of Leg i @ 541~65 '~' N and 1596.41 '> W' from SE Corner of Sec. 23, T8N, R13W'. S.M. 7. Permit No. 67.,51 8. APl Number 50- 733~22041-.00 OTHER [] 9. Unit or Lease Name MBS 10. Well Number C 34-23 11. Field and Pool Middle Ground Shoal 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106'~' D.F. I ADL 18756 12. Check Appropriate Box To Indicate Nature of NotiCe, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~( Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See Attached, Alaska 0ii & Gas Cons. Commission AnChorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date 10/4/83 Conditions of Approval, if any: Approved by ORIGINAL SIGNED BY LONNIE C. SBITll Approved CoDy Re, turned x .. By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~ )UTHORITY FOR EXPENDITU :~ , PRODUCTION PACl FIC DIVISION HOUSTON LOCATION OF PtqOJECT AJqI~q(:~I~FIIATION NO. C-34-23 Platform C OA,. ,..,AR.O Middle Ground Shoal Field 9/14/83 Cook Inlet,"Alaska ~r. LOC^T.O. NU..E, III II I I IIII II II WORK SHELL'S 33 % SHARE ORDER TYPE DESCRIPTION , NUMaER 100~ CO~' 8ucx3E'r NON-SUCkLe' E~,I~ TOTAl. i i ii R&R Obtain profile injection $15,000 $5,000 $5,000 survey in well C34-23 Non Operators Approval Not Requi red Requested By' J.H. Douglas T.S. Burns · u.-~'m'A~ r$!5,ooo $5,ooo $5,000 i /'kill BUDGET AVAILABLE IN .BUDGET RETIREMENT EXPENSE' i POSITION NEW CAPITAL FUNDS REQUIRED BY BUDGET' REVISION TOTAL COST ~'- ~.000 , i JUSTI FICA, TI ON: ........ See attached justifiCation. RE[EIVED OCT 1 2 Alaska 0ii & Gas tuns. Commissi,an ' ' Anchorage [] CONTINUED OVER ...... RECOMMENDED APPROVALS , Justification Injection Survey C34-23 Middle Ground Shoal Field Funds totalling $15,000 ($5,000 Shell's 1/3 share) are requested to obtain an injection survey in well C34-23, Platform C, Middle Ground Shoal Field, Cook Inlet, Alaska. Well C34-23 was drilled and completed in October 1967. In 1969, Well C34-23 was converted to injection with an initial injection rate of 4500 BDW. In April 1982, C34-23 was acidized with coiled tubing. The injection rate increased from 1600 BDW to 1900 BDW. The rate has since declined to the current rate of 1500 BDW. The formation of bacteria and scale during recent frequent shut-ins is believed to be the cause for the injection decline. C34-23 is located on the southern boundary of Pattern #5. Pattern #5 currently produces 1700 BDO, 2700 gross, and is supported by 3200 BDW injection. Pattern #5 has previously responded well to increased water injection. Acidizing three injectors (C41-23, C24-23, and C34-23) is currently being evaluated to further increase water injection. Additional water breakthrough recently occurred in C43-23 (immediately north of C34-23) in one of its producing members. The breakthrough was noted by a 200 BDO drop in oil production with cut increasing to over 90%. The well is currently cleaning up and most of the lost 2roduction has been restored. With water breakthrough occurring in C43-23, it is recommended that profile information be obtained before further stimulation is attempted. This will prevent further stimulation of a watered out or thief zone. The profiles will also be helpful in determining which zone watered out in C43-23 and estimating the well's future productive potential. The last profile information for C34-23 was obtained in September 1980, and was scheduled for an R.A.T. survey in 1983 as part of the reservoir maintenance program. Your approval is recommended. Prognosis Injection Profile Survey C34-23 Status' Injection 1500 BDW at 3500 psi. See attached completion details for perforations, sliding sleeves, packers, gas lift mandrel depths, etc. Objective' Determine injection profile. Procedure' lo Rig up wireline and lubricator. Test lubricator to 3500 psi. Make drift run to bottom. Record on log heading. Rig down wireline. e e Maintain constant injection rate at 3500 psi pressure for 3 days prior to and during the survey. Record on log heading. Rig up service company's lubricator (high pressure - wireline), stuffing box, collar locator, continuous flow meter, and radioactive tracer with ejector and two radioactive detectors. e Tie into depths with collar locator in casing. Log perforated interval (8097'-9419') with CFM and determine profile for water leaving tubing or casing. e Use R.A.T. to determine profile behind tubing and vertical fluid movement behind casing. e Log tubing to surface with CFM to determine tubing leaks and/or fluid leaving tubing and re-entering at a lower location. If casing leaks are suspected, confirm and locate using R.A.T. 7. Rig down service company, continue injection. E ?!0 }~A.",'L VA[,'..rF, NZPPLE · . · . c.,~s};i, lo: 7"' 26~..,-.'~?/~ PLVfD.' 9h40' '.t'us;El, s: ..3-~-" 9.3// ~r-80 .. PEPO"S. : 8.,O97-8h39' ON-Ga, 8,698-8,8)-~b. ' . .'.' .. 8~ 908-8~ 949' 8,966-9~ }.~19 ' }tK-HZ · , , . '.' , , , .. . , ,. , 1970 ~:,r//2'® · · · . , · ., . ~e~ 113! ~ 5;, 7. o7, ., . ~M //I, e 6,693' .. . . · .. . . . .. . .. ., . . ., . .o. · · . . · RH-1 PAC]gER '@.8 ~ ~68 ' RH-1 PACKER e- 8,9~" X-N IPPLE e 8 ~ 961' -NIPPLE e 8,973 ' Pa aa 93 WES'FERN E&P OPERATIONS SHELL-ATLA NTIC-STANDARD I/ i f · I /:o ~-o, / ~ -~.- ~ 4-- ~ .......~.~ ..... 1-- ; ~- ~ / --~~ / / / 0~''4 : ' I .- -~, ~ :, ~ ! ~ INJ~C ~ION WELL , / , ~4-~ I : /~-+~' ~ ~ ~P.~ PLUGGED & A~ND. . . / : · O"' I: '"we/i~. ,, i ~ ';---~"/ ~ l~_. 400,0 ~~ ~i ~- ~ ,.,- ~ ~ SCALE IN FT ~ STATE OF ALASKA ~_. ALASK,P'~IL AND GAS CONSERVATION r~MMISSION SUr--;DRY , OTICES AND REPOR1 ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Shel 10i 1Company 7. Permit No. 67-51 3. Address 8. APl Number P.O. Box 92047 W0rldwa~v Center, Los Angeles, CA 90009 50- 133-22041 9. Unit or Lease Name NG$ 4. Location of Well Conductor 6, Leg 1, 5.77' South and 0.81' West from center of Leg 1 which is at 541.65' North and 1596.41' West from Southeast corner of Section 23, T8N R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 106' D.F. 12. I 6 . Lease Designation and Serial No. ADL 18756 10. Well Number C 34-23 11. Field and Pool Middle Ground Shoal Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) {Submit in Duplicate) Perforate D Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation ){~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other r'l Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed' Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). · Please see attached. Alaska Oil & ~' -, uaw Cons ~:',nchorag~ 14. I hereby certify that the fo~egping is true and ~prrect to the best of my knowledge. The sP~ ~elow f~r Comm~on use For: B. Nevi I 1 Date 4-22-82 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Coma,ss,on Date Form 10-403 Rev. 7-1-80 Subm,! "lnlenl,on$" in Tr~phcate and "Subsequent Reports" ~n Duphcate STATE OF ALASKA ~ ALAS,.A OIL AND GAS CONSERVATIOI. -;OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1, DRILLING WELL F-] COMPLETED WELL ~ OTHER :2. Name of Operator Shell Oil Company 3. Address P.O. Box 92047 Worldway Center, Los Angeles, CA 90009 4. LocatFon of Well - Conductor 6, Leg ] 5,77' 5outh and 0,8]' West from center of Leg ] which is at 541,65' North and ]596,43' West from Southeast corner of Section 23, T8N, RI3W,S.M. 5. Elevation in feet (indicate KB, DF, etc.) lf16' D.F. , 12. 7. Permit No. 67-51 8. APl Number s0:133-2004] 9. Unit c{r Lease Name MGS 10. Well Number C-34-23 11. Field and Pool Middle Ground Shoal J e. Lease Designation and Serial No. "G" Pool ADL 18756 'Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in DuDlicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate ~C~ Abandon [] Stimulation [] Abandonment Repair Well {--} Change Plans [] Repairs Made [] Other Pull Tubing ["1 Other [] Pulling Tubing [] (Note* Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of Itarting any proposed work, for Abandonment see ;20 AAC 25.105-170). Please see attached. Subsequent Work l~epor-ed ' Signed //L~__~_~~M~ T,,eMgr. Prnrl,,ct'ion Administration Thespace~e,owfo;Commi~on-use For' B Nevill 2-25-82 Date Conditions of Approval, if any: IlY C. $ l'rff Approved by ~ COMMISSIONER Form 10-403 Approved Returned By Order of the Comm,ssion Subm,! "intentions" in TriPlicate Rev. 7-1-80 and "Subsequent Reports" in Duplmate AUTHORITY FOR EXPENDITURE oe,.r. ' ............ ] BF',,~'~%FF~C~ '' I OF~G~N,A,'n~',~ OFF~ ' % '" ~:L ~' " ' PRODU~IONI PACt, ~C DIVISIONI HOUr. ON ....... ~~ OF ~~ ~RIA~ C34-23 PLATFORM C . MIDDLE GROUND SHOAL FIELD 12/28/81 I COOK INLET, ALAS~ .................... ' ' ~RK SHELL~33~ SHARE , ,, ORDER ~PE DESCRIPTION NUMBER 1~ C~ Bu~ N~-BU~ , , .,~ ,,- ,i, , R~ Acidize C34-23 injector through coiled tubing $40,000 $13,300 $13,300 Non-Operator approval not requi red Requested by: ..: ~ J.H. Douglas B.N. Osborne R.V. Hill · K.J. Evans . (~g) SUI--~TAU $40,000 $13,300 $13,300. ........ /~111 '~ m., lU~ AVAILABLE IN BUDGET RETIREMENT ~SITION NEW CAPITAL FUNDS REQUIRED BY ~UOGET REVISION TOTAL COST , ~ ~J~ ~UU JUSTI F I CATI ON: SEE ATTACHED JUST[F]CAT[ON MAR ' g CONTINUIO I I III II I I RECOM M EH DED ApPROVA~ , , , ~ ., ~ ,,, . , JUSTIFICATION C34-23 Funds totalling $40,000 (Shell's 1/3 share $13,300) are requested to stimulate the lower Hemlock sands in C34-23, Platform C, Middle Ground Shoal Field, Alaska. The economics for the job are as follows: ~ SHELL NET TOTAL GROSS Expenditure $13,300 $40,000 Oil Increase (BPD) 14 42 PVPAT La 14% $55,000 $165,000 % PVPAT 400% 400% Payout (months) 4 4 (0.60)($55,000)- (0.40)(0.5)($13,300): $30,000 The purpose of this stimulation is to improve our injection capabilities in the lowest 3 zones of the Hemlock formation (HK/HN-HR/HZ), especially the HR/HZ. Increasing injection into the 3 lowest zones of the Hemlock will make our secondary recovery program more effective because these zones are relatively unswept in comparison with those uphole. As shown in the table below, the yearly production decline in Patterns 6 &'7 is much greater than the total average fluid decline (for calendar year ending October, 1981). These rapid declines in the south portion of the field are due largely to poor waterflood management in recent years. The HK/HN through HR/HZ zones contain 57% of the STOOIP in Patterns 6 & 7. In order to improve our recovery, we recommend stimulating these zones to increase injection volumes into them. We estimate that the recommended stimulation of C34-23 will increase injection into the lower zones by 165 BPD. Based on a 0.25 BO/BW injected ratio, we expect a production increase of 42 BOPD. YEARLY sAs MGS TOTAL PATTERNS 6 & 7 10/8,0 10/81 DECLINE FIELD DECLINE Gross Production (BBLS) Oil Production (BBLS) 39589 30382 23% 11% 19807 14302 28% 18% With the use of coiled tubing, we will be able to spot acid at the desired perforations so that selective treating will be possible (below the bottom packer). By-taking this approach, we can avoid a much more costly (and most probably unjustified) job of pulling the well, stimulating, and altering the downhole completion. This job would be quite risky because of the number of packers in the well (3) and the length of time the completion has been in the hole (ll years). In addition, because of poor tubing integrity (leaky gas lift valves and sliding sleeves), batch treating from the surface with diverters is un- acceptable. We feel that the recommended treatment 'in C34-23 will make our injection program more effective, thus. increasing production and slowing decline rates in Patterns 6 & 7. Your approval is requested. MAR 1 $1982 C-34-23 STATUS' OBJECTIVE: PROCEDURE: NOTE: 'lo e o ° 5~ e e . Currently injecting 1635 BPD into the GN/GO, GR/GS, HI/HK, HK/HN, HN/HR, and HR/HZ. Last RAT survey 9/80 results are as follows' ZONE PERCENTAGE GN/GO GR/GS HI/HK HK/HN1 HK/HN~ HN/HR~ HN/HR~ ' HR/HZ~ HR/HZ~ 0.07 0.07 O. 06 O.11 O.24 0.16 0.23 0.03 0.O3 1. O0 Improve injection profile by acidizing the lowest zones (HK/HN - HR/HZ) through coiled tubing. (Shut-off injection +_48 hrs. before rigging up coiled tubing unit). Rig up slick line, test lubricator to 3500 psi. Run 2-1/4" tubing drift to bottom + 9440'. Tag and record depth. M.I.R.U. Otis coiled tubing unit and Dowell acidizing equipment. Test tree and coiled tubing to 5000 psi. Test hydraulic system and BOP. Run tubing in the hole slowly (no more than 100 fpm). Tag bottom (9440' PBTD), if fill is above bottom perforations at 9419', notify K. J. Evans (713) 870-2342 or (713) 531-8676 (home). With coiled tubing at 9419'. Spot 710 gal. of 7% HC1 with 0.3% W-35 0.2% F-75N and 1.0% A-200. Slowly move coiled tubing uphole while s~ot- ting acid in order to cover all of the perforations (8966'-9419') with acid. Pump 8 bbls. of injection water to clear coiled tubing. Stop coiled tubing at 8980'. Wait 30 minutes after clearing tubing of acid and pump 17 bbls injection water. Run coiled tubing to 9419'. Spot 710 gal. of 12%-10% HC1-HF acid with 1.2% A-200. Slowly move coiled tubing uphole while spotting acid in order to cover all of the perforations (8966'-9419') with acid. Pump 8 bbls. of injection water to clear coiled tubing. Stop coiled tubing at 8980', wait 30 minutes after clearing tubing of acid and pump 15 bbls. injection water. (Repeat Steps 6 & 7 two times). After repeating Steps 6 & 7 the second time, pump 300 bbls. injection water. While moving coiled tub~{]~~,.~down through treated interval. MAR 1 5 1982 Gas Cons~ Commissio!'~- e POOH and rig down. Put well on strip chart, return well to injection at 3500-psi and test. Report rates to K. J. Evans and J. R. McGregor in Houston. NOTE' · While working on water injectors, do not leave coiled tubing standing on well without fluid movement. Blow coiled tubing dry with rig air after rigging down. If rig a_ir is not avail- able, cover coiled tubing reel and keep heated or circulate' 50% methanol and 50% inlet water. APPROVED DATE RVH'ckk RECEIVED OJJ & Cas Cons. Commission Anchorage NO BALL VAL~TE I']IPPLE KBt{ ~IDR~IAS 9 ~-D. 1. 2 2. 4~302' 3. 5,7o7' 5- 7,302' 6. 8,528' 7. : 8, 828, 8~2~, PB~ ~0' - 8 Rd. I · . e, KBM //5~ @ 7,302' ~//6 e 8~28, xo Sr.~VE ~ 8, 856' . RN-1 PACKER O 8,860'. '. X-~IPPLE O 8,866' " ,...., ~8~?;.-..-". ~.~ e 8,~'- ':' '-' --':t'sr~.' ~,hho' - Page 91 o .,Naska Oil & Gas-Cons. Commission · Anchorage ;7>'oe' ~ol. I oc' ~1~.1~ RECEIVED' · MAR 1 5-t~- X-N IPPLE 0 8, 961' ~. =, ...- 7~0 .¥ 7 Co;! I · I I I /0o ~ RECEIVED ~.<- ~,~ z_ MAR 1 5 1982 "<'~' ~' '~.$k,1. Oil & Gas Cons. Commissio~ ~ 0 ~ .o ~chorage .. CO ! L TUB I NG sPEC I F I CAT IONS L e n_~9_9_~ Width __ -- Power Pack 8' 4'/" Blowout Preventer 4 ' 2' Injector Head 5'6" 4' Reel lO' 6" 8' Operators Console 9' 8' ' 4" 5' lO' 6' " 6800 tbs. 538 tbs. 5500 1 bs. '12,800 1 bs. 3800 1 bs. De___s c r i p t i on -- Working Depth (1.255F) Working Pressure/Max PSI Tensile Strength/lbs. Tubing O.D./in. ~Tubing I.D./in. Wall Thickness/in. Capacity of Tube/gals. per lO0 ft. Capacity of Tube/bbls. per )000 ft. Displacement of Tube/gals. per 100 ft. Displacement of Tube/bbls. per 1000 ft. Tubing weight/lbs, per ft. Standard Pipe 12,500 5,000 lO,O00 l. 000 .874 .063 3. 120 .742 .964 .230 .630 _Heavy-Wall Pip_e_ 12,500 5,000 12,000 1.000 .'840 .081 2.880 .650 1. 200 .290 .810. RECEIVED MAR 1 5 1982 A~aska Oil & Gas Cons. COIL .'. o '-i"L~ E~t Ix/G · .o · : · , ; .... ., · · CODE _._50._t33.2004t lease Date:~.11~21.67: .. State of Alaska Department of Natural Resources DIVISION OF I~INES AND HINERALS Petroleum Branch INDIVIDUAL WELL RE~ORD Sec. _ 23_ T. 8~I R. 13 ~. S Heridlan _ ~c '" t ~--- ~ ' Permi t No. I s sued 9-11-57 Operator Shell Of~l Co, Location (Surface) C,le~ 1 Lease No" ~L- 18756 or O~ner .... :~ddle:~OU~_:~al .... Loc. (Bottom)_ ~e116~,2 ~ ~sLl°c~&lglS535'88~ ~L.FSL &See.1597,2223 F~L_ Sec. 23 ... ... ~el 1 No, C-3~23 Area ~S : Spud Oate.,9~!3-~= .... .= Drill ing Ceased., !0-16-67 Total Depth 9~662' ,r _ ~_, ~. J , , ,, ,_-- ~ - ,~ , ,~ .....~- a . ,, Suspended :~ ......... Abandoned E Completed (F-GL-P)._!O_-~l,67 ..... IP ..... 3993_. · B/D, Grav_,~API Gas ~_!.66~!: ~__ ~HCF/D, Bean 128 _/614 CP 0 psi, TP .: ..:__!10 _ psi Casing: =Si_z~? ~ SxCmt. Perf:8/+07'~39'-.8698.8728: Plugs g~99-88~ ~ 8908;32; 8939.~9-1 ~ .5~ ~ 8966-9088'~ 9~03-6,'~ 9172-92Eq'[ 9268 ~-78 ~; 9294 ~-9~9 ~ , ~29 ~' ~ _. ............................ - _,., ......... , ..... --.:- - GEOLOGIC FORHATIONS Surface Lowest Tested Name PRODUCTIVE HORIZONS Depth Con ten ts IIIL . __ J.~ I__t I , ____:_ ::_: - : ..... : _.' :-: _-. : . _ : : - : ..... WELL STATUS Year Jan Feb ; Nar Apr Hay June July., Aug Sept , Oct Nov Dec ,, -:~'.~J' ~;_ = ::.::~:~-:~_-=::~ ~:.'~ :~' -: ::,FC,,,:; ~]~:: : , ,,:,& 7: ~: ,~:-;:, :-: ~ - ' :~:'~:,_,,'-~ :., _':-: ' -, ~ ..... r~7': ~ ~T .-__7 =_.:- _:-~ :" ,7: 'j'_ ~ .... i Contractor=__ Sant~ l~e; _~!_~, _cO_'-. ........... ..:._ . =_ SHELL OIL 430 7TH aNCHORAGE. COMPANY AVENUE ALASKA 9950~ November 17, 1967 CONFIDENTIAL MATERIAL STATE OF ALASKA Division of Mines & Minerals 3001 Porcupine Drive Anchorage, Alaska Attention: T.R. Marshall, Jr. Gentlemen' Attached are two copies of the Well Completion Report for our SAS Middle Ground Shoal C-34-23. Included with the report are the following data: Composite Log (Sepia & Print) Directional. Survey (2) Well History (2) Very truly yours, .~D~.~Allen Division Exploitation Engineer WH/n~n Attachments RECEIVED NOV ~0 !~7 I~tlVI$10N OF MINES & 7 _ structions on OIL AND GAS CONSERVATION COMMITTEE reverse side) [ n i ' J WELL cOMPLETION OR RECOMPLtTION REPORT AND LOG* i i _ b. TYPE OF COMPL~-TION: %VELL OVER EN BACK P, ESVR. Other NAME OF OPERATOR Shell ~)il Company 3- .~ ~ 430'Seventh Avenue~:/An:~h°rag. e, AlaSka 99501 LocATIoN O:F .WELf-(R~port locatibn cldarly and in accordance with any State requirements)' At sur~aeeCo:nductor 6. @b5.'77 'S & O. 81tW from center lek 1 @ 541. 65'N and 159641'W-:~rom SE corner, Sec. 23, T8N, RI3W, S.M. At top prod. interval reported below ~ I '~- I ' )' "~: . 2.72 N & 8~86 W:o-: surface At total depth ~ I5-~,-00'.N & 23.'10'W of surface DESIGNATION AND SEI~La_L AIO. _ ADL 18756 ?'IF IIN-DIA.N, ALLOTTEE OR TRIBE NA2~E 8. ~UN~,F~ OR L~SE N~E ,,, Middle Ground Shoal 9. W~L 'NO, c-3 -23 F~ AIN-D POOL; OR WILDCAT Middle Ground Shoal ~EC., T., R., M., (BOTTO~ OBJECTIVE) Sec.~ 23, TSN, ,R13W, s.M. 12~ pIRRaNIIT 4 -; 67-51 9713-67 , J' 10-16~-67 -.~ [~ 1.0-21-67 [ D.F. 06 18. T~D~,'~ & TVDpg: PLU~, ~.. MD~& ~; ~L~ CO~L., / m. ' '" INTER~ALS DRILLED BY ' '? - .... - '['- Z . :' : .' [ ~W~Y ] aO~AR~ ~0LS .... C~U~ ~OOLS (9a3 'WD)? t - ~. PRODUCING- ~~(S), OF ~iS ~M~TI0~,'~M, N~E (~ ~ ~)* ~. W~ DIRE~ON~ SURV~ 8-407 (TTM 9402 ') 9419 (TVD9411) TYPE EL~C~ItlC A_ND .OTHE~- LOGS. RUN- ' plL, mC, Formation Factor Porosity,. CBL -~;~ ~'~"~' [ ~- - ~ ~ ' [[ CAS~G RE~ (Re~ all ;strips set in well) C~G SIZE ~IGC, LB/FT. DE~ ~. (~) HOLE 10-3/4" ~0.5 J ~ 2007:" 15" 7" -: 26- &' 29 I,~'-~9545' 9-7/8" 26. LINER lq..E C 0'R~D ~? dS. PEI~ORATIONS OPFdN TO PRODUCTIOI~T ~ (InterVhl. size and .number) yes [ r¸ cm~ ..r~TLWG 'm.mco~ AMOUNT PULLED 1850 SaCks .~ None 1100 8acks None I ' 27. TUBING RECORD SCltEEN (MD) SIZE [ DEPTH SET 0VID) 3-1/2" 8360~ 7127 I I 29. ACID, SFIOT, F~'~, C~NT ;SQU~E, ~C. 4 jetS/ft 8407'8439' , 8698-8728' , 8799- ~-D~f~mV~(~>.:'[ a~ov~m~o.~m~u~ 8844', 8908-893a"~; 8939-3849' 8966-9088' 9103-91649419,.. ', 9172-9250', 9268-9278. ', 9294-. i -; ' ~ODU~ON . PACKER SET (MD): DATE OF Tml~T, II-~OUI~S TF_~TED '[C~HOI~E SIZE [PRQD'N FOR 10-26,:67, ! - 24 [128/64 ] ~' t 3993 ~' ~OW, EBING l~SmG ~sU~ Ic~~~ 'OI~BBL. GA~. 1~0 I 0 . ] > i993 I 1661 3i'. D~SP0S~T~0N OF OAS (8old, used for ~uet, vented, etc.) ' DATE FIRST PI~ODUCTION [ PltODUCTION METHO,D (Flowh~g, gas lift, pumped--size and type of p~p) [WELL STAES (~oduc~ or 10-22-67 ~ Flo~id~ ] Producing OIL---BBL. G~uS--AiCF. WATER--,BBL. [ GAS-OIL tLP~TIO 1661 ' [ ,,16 WATER--BBL. [ OIL GRAVITY-~UPI (COllR.) ] 16 ] 35.2 t TEST WITNESSED BY Vented · S2. LIST OF ATTACHMENTS Well History, Directional Survey, Comoosite Lom (print & seoial , SIGNED //(c.. "~/'~/~'r/~(~'~t'~ --, 'r,TkE ~:: .;Diu~s~on. . . . Exploitatzon E_gr *(See Instructions and S~ces [or Additional Data on Reverse Side) ~UV ~u I~O/ DIVISION OF MINES & MINERALS ~.~JCHO~,AGE INSTRUCTIONS ,, -. ~ -General: This form is' designed for submitting.alcomplete and cor~;ect well-completion report end log. on i~ . all tyPes of lands and leases in Alaska. _Item: 16:..Indicate Which' elevation-is used as~ reference (where not otherwise shown)for depth 'measur~e- '~ ments_given'in ether spaces on this form and imany attachments. .. " ~'- . ' -Items ~0, and 22:: If this well is completed ~for sep~ii:afo productiOn from more than one interval' zone '"' (multiPle completion); so state in' item 20, and' in itern 22 show the prcducing intervalr, or intervals, top(s), bottom(s) and name (s) (iF'any) fdr.only the intervall reported' in item 30. Submit a separate report ' .. _~ (page) on this fOrm, ladequatelY identified, for'.each adcti'tional intelval to-be Seperately produced, show- ing the ackiitional data pertinent to such interVal. - :' ' Item26:= "~acks Cement"::' Attached. supplemental records for this Well should sh°w the details: Of_a~{.y. m'ui ..... .. .?~ .. " tiple stage cementing. anci~'the location of the cementing tool. : '~' :' -' · Item 28: Submit a s~,par~te.completion ~'e'port o~' tl~'is form for ieac~'inter~al to b~' separately p~'0ducadl ~: . ..... (See instruction for item~,.20 and 22 above). "i~i- i ..... ' ''~ ......... 34. S~MM/kRY OF F~I~4~ATION TF-~TS INCLUDIN(] INTERVAL TESTED, P~qURE DA~A ~ ~OV~ OF OIL, G~, --- ' ~6. CORE DATA.. A~ACI{ ;-' ' .... 3:. AND DE'PEC~EI) SHOWS OF OIL, G~ OR WA~. : . Well History C34-23 Middle Ground Shoal Field September October October October May October April August June July August September April 1967 1967 1969 1970 1971 1971 1972 1975 1976 1977 1977 1980 1982 Spudded Completed Convert to injection Pull and isolate HI/HK thief zone with packers R.A.T. survey Bacteria destruct stimulation Acidized with 28,000 gal. 2-1/2% HC1 and 35,000 gal. 12%-10% HC1-HF Caustic and acid wash R.A.T. survey Stimulate with 10,800 gal. 12%-10% HC1-HF R.A.T. Survey R.A.T. Survey Acidize with coiled tubing. WELL SHELL OIL CONtPANY ~'~ RECOMPLETiON REPORT C 34-23 SHELL OIL COMPANY · =1 -- il Middle_ Ground. m Shoal. 3/25/82. · 3/26/82 i i i ~~ .... _ 106'.D.F. 74 ~o,~ 9545 9440 ~rker Ho/iz~"ns ' · i m i mm, _ i i · i -- b m mi m mi ,1 ,m,l Im m i i · mm [ ~ Production Data Unchanged - -- _ i ~mmmm m mill ~ _ i m k I _ ] -- m~ immm .... I I·1__ j m $ ---- - ii i 7 ',,~ 26 ~, .2,9# N-SQ~,--~d -, 9545 _,'~d'~ ...... ~..=e~.~d, .~ , __ I mm Im~ m ~ mm mm m ,,, m m ,, m m m m m m mL m m m m ~e--~ :' ..... ~" _ ,, ~.~ o~"~ '~ .... ~ - - , . ~~~., au2as g097/~439 m Il 11 ' HI/~K 890gm/89~9 ii ' H~/~Z 8966/9419' ~ .... Initial Production mi iml im ~m i u , ,, i m ,, ~ ii ii I · ii II m Adotl. Prod. D~-ta Calculated Potential - -- I i i i i m -- _ il mi - · s i __ i mi - ] mi -- m ..... _ i i roll III IL L i I i · Iml · iiu m~ -- i m ~ -- ,11 j[ ~ i m I i _ _ m Improve injection profile by acidizing the lowest zones (HK/H~ -~HR/HZ} through coiled tubing. Aiaska Oil & Gas Con,s,,fiom~,~ IL I MIDDLE GROUND SHOAL R~C,N;] ~rlqCNIH<~ C-34-23 . - "' ' "" ' Kenai, Alaska 3/25/82 3/26/82_ . Platfom .C .... I ii I I I IIIll I I I I I ! II I I I I III I1 · II II I ! ' "' " I II I I II I ! STATUS' Currently injecting 1635 BPD into the GN/GO, GR/GS, HI/HK, HK/HN, HN/HR, and HR/HZ. Last RAT survey (9/80) results are as follows' Zone Pgrcentage GN/GO 0.07 ' GR/GS 0.07 HI/HK 0.06 HK/HN1 0.11 HK/HN~ 0.24 HN/HR~ ' 0.16 HN/HR~ 0.23 ' HR/HZ1 0.03 HR/HZ2 0.03 PROPOSAL' Improve injection profile by acidizing the lowest zones (HK/HN - HR/HZ) through coiled tubing. · 3-25-82 2'00 PM. Rig up Otis coiled tubing unit. 5-00 PM. Rig up Dowell equipment. 6-00 PM. Held safety meeting with Shell and contract personnel. 9:30 PM. Pressure test Dowell and Otis equipment to swab gate to 5000 PSI. 10'30 PM. Circulatedieselout of coiled tubing. 11-30 PM. Started running in hole at 60'/minute circula- ting with filtered sea water at 1/4 bbl/min, at 3500 PSIG. Holding 1500 PSIG on tubing annulus back pressure. 3-26-82 3:30 AM. Made 3 passes through perfs from 3966' to 9419' with coiled tubing unit. Circulating filtered sea water. I! II I II I ! !iiiii . EECi ~ ~M!DDLE GROUND SHOAL C 34-23 ' Kenai, Alaska 3/25/82 I:l~Ol:t~ 3/26/82 Platform C I II II I I II III II II I I I I I Ii I I II I I I ____ ! I I I I IJ III I I II IIII I I II I I I I I I I ! I Jl I 4'00 AM Pumped 700 gal 7% HCI. to 4'45 AM '4'45 AM to 6-00 AM Pumping in HC1-HF 12%/10% acid with 1-2% A200 across perfs form 8966' to 9419'. 6:00 AM Completed 2110 gals HC1-HF 12%/10%. Started pumping~HC1 7% 710 gal. Spotted across perfs from 8966' to 9419' 8'30 AM Chased mud with 20 ~bls H20 filtered. 9'30 AM Pumping 100 bbls filter sea water at 3500 psig 1/4 bbl/minut~. 2:00 PM Rigged down 'and moved rig over C-23-26. Rate on to 3:00 PM C-34-23 2650 bbl/day at 3500 psig first 2 hours. : I o ~as C]ons. Oommission I I IE I1[I WELL ,* SHELL OIL COMPANY -RECOMPLETION Marker Horizons -Depth i lU i! · Location REPOF~i:~s~oN o,: oil #casin~ "casin[~ ',ca,sin~ ",casin~ *'liner w.s.o.@ ..... cemented at ' cemented landed/hung cemented thru ]Mr~s. at landed/hun~ at , ,top , at " h.~ Production Data Gross Flui~L*B/D Clean Oil-B/D. Initial Production ,,.. / Adetl. Prod. Data Calculated Potential Date Date i i ,ill, i i ii i ii ii i i i · iiii il i i i i i i i ! Il J _.Signed ~PD298 (Rev; ~.6~) P'r,n;ea m u.=.~. GHELL, OIL COMPANY ' RECONDITIONING REPORT - COUNTY ~RO~ ~ PZmOO 'to i ~-~ ..... , , ! i i. ' i ~ ,,.. · % , . , , il , , , · ,,, ' ' ' :REMARKS (SHOW IIZ~ AND 'rYPI TOOl~ RUN) · - . . . -. . . . ~ . / ~ , C.~pte~ed ri8 move and ftu[0hed ri~tu~ up. Bi.ed off cub/n8 and cau~u~. Eemoved Lree. E[~ed uP ~ise~ and BOP stack. Tee~e~ al[ BOP hydraulic ~unCt[OnS to [500 psi. ~e[d [0 mtnu[es okay. ~nsea~e~ donu~ .. ~nd pu[[ed-packe~ ~oose ut[h [[5,00~ bODE load (block ve.t~h~ 20,000 ~ included, sLrLu~ ~et~hL approx-t~ely 8~,00~). C[ose~ hy~[[.bas and -injected overntSht do~ annulu~ at [600 B/.O rate wL~h [000 pat, . . · . . . . . , _ _ . . - Stopped in.iectton and bled d~n ~11.. ~ulled and singled d~n ,, ~ ~ bLt~ ~c;~er, b~p~; su~ ~,~ ~ co~Ja; clean o~t - 1200 B/D rate vit. h 1000 psi surface pressure, _ ~topped. /n~ect. ton. Bled casing, Continued tu hole ~tth clean .out string. Nound hard-~[1 ae 9621 (R,T,), Dr[[[ed and ~vetse circulated nu~ fill 962I - 9~0. Pulled. ~de up comp[eC[~ s:rtug and stetted 'running tu bore, ~hut dovn overnight, vtth ~000 B/D ~nJec:'Lon rate at '1000 psi. ,, ~, ,, /~ .... ~ CONDITION AT~OF PERIOD GONDITION ~ STARTING WORK HOLE . [ CASING SIZE I DEPTH S~ (CROSS OUT AL~ BUT APPROPRIAT~ tn · ~. ~.~.~ ~.~cr~v. ~~ / ~ ~. ~o o.u.~. ~ -- ,, -- ~TION OF PUMPING E~UIPMENT (UNLESS WEL~ WAS ORIGIN- .~ , ,. ~ q ~ ~ /~, ~ ~ l.~qS~ ~ s.u~, ~ow. o.~.~o.s .... - ,,,,, ,, , , .... , _ .~. . , - . _ , ,, SIGNED -PD298 (Rev; ~6~I P'un~ea tn u.o.~. .~ 8HEI,,I,, alL (~OMPANY ~ ,~. 'z:~.. ~~ ~ RECONDITIONING UNTY 'FRO~Id PERIOD TO REMARK~ (SHOW IIZ~ AND I'YPI~ TOOI,.~ RUN) .Stopped t~Jec~In~ and bled d0~ c~L~, Con~[nued runni~ tn hole ~iLh tubing, packers,'and jewelry. Rabbited all tubing, ~de ,up tubing hanger and tagged-tubing hanger sea:., l'tc~d up 6 1/2 ~eet slack o~, Schl~be. rger located packers ~* high, Pulled Schlumberger, , : A'd~ed 6~ pup ~oint unde, r hanger, ~nded and picked up a ~/2 feet. for slack o~-f, Ran,and seat. ed Q plug. '~illed tubi~8, Set bokt~ packer vith 1200 p~ai, slagk~fl of~ 1 fOOL. Set. middle packer vlth 1500 psi, SeC Cop packet -J~ -':~-1700~T~'~:~ ~'" ~Slacked-':°'~-3 i/2"f~eC 'and ~anded donut in tubing hanger seat. Book load ~96,O00-(f, hloc. k-~etght 20,000 (~, a[ecked o['f ~etgh~ 6'~000 fl ~: '(32.,000-~i on .pack,a). ~(~ened .top.sl. tdtng $[eeve :o equalize tubing'.~nd cauing. Pulled 'q plug. -Removed'BOP slack and t~ser. 8e~ L~ and teated tt Lo 3000 pat. Held [0 minutes okaY. Rigged injection [the. Opened ~o lo, er eliding sleeves and teEN,ned ~eti to injection at &000 B/D tats ~tth 2000~ pat att 7:30 ~ . KB~ (fl ~/1090 psi -3/16' gas I ifc valve, at. 239a KBH fl2 v/ltl0 psi 3/16" gas I ifs vale. at 4309 KBN'{~3 -~/1120 psi 3/16" gas lift valve, at 5707 KBN ~14' v/il00 psi l'/~" gas lift valve at 6693 .' KBH ifS' ~/dt~ va ire ar 7302 KBN 86 ~/~'~ valero-at' ........ 8~28 Siid/t~g sleeve at 856~ ' RH 1 pac.~r aC 8568 ~N (~7 ~'/d,)~.my valve aC 8819 Sliding sleeve ac ' ". 8856 " RB I packet ac : '8860 - ' ....... at /PPc ' '-- ~ ~8 ~/d,~ · . 8898 ~ltding sleeve at .......... "'~- *' 8951 RH I packer at 8954 X nipple at 896[ · Q nipple at 8973 . . CONOmON AT ~ OF. eZmOO COaOmOa ~~ARTING WORK HOLE · I CASING SIZE I DEPTH 6~ (cRoss OUT ALk BUT APPROPRIAT~ ITEM~) . DE~H ~ST (RD, OR D~,) .... ,, TOP FISH {F) OR JUNK (J) ~,~ - DEPTH PRESENT [;F[~Vf . - BAD C8~. (C) OR LINER , NOTE--IH ADDITION TO REPORTING ROUTINE RECONDITIONING OPER-I ATIONS, US~ THIS FORM FOR REPORTING THE FIRST INSTA~ ~TION OF PUMPING EQUIPMENT (UNLESS WELL WAg ORIGIN- ALLY COMPLETED ON THE PUMP). BAD CASING. FISH LE~ IN DRIL~PIP~ HOLE, ETC., THAT MAY OCCUR AS A RESULT OF PRODUCING ?~E" ,, , , , .... SHUT DOWN OPERATIONS ..... 81GNED i ii J i ii ' ' " T" LATITUDE DEPARTURE :'SECTION AS. STA.~ANGLE OF , 1" .. ~TH DIST., . . COURSE TOTAL LOSS DEVIATION NORTH. ! SOUTH EAST WES NORTH SOUTH EAST ! "WEST ' , _ ) (¢_L~c~1 ...... ~.7~0%o' ?~¢o, '7500 5 i;:;z- E rib ' o~ G;;to ... , 7otj · o" ~ oc, 12.¢0o , ~ ~'4- ~ o7 05 ~2~I ?o .' " ~.~ ~5- o~ o, ...... ~ ' ,, , ~ . ,,, 7~ a~ -o,~$' ~~ 0,?5 ~ 5,4~ o ~ ,..... ~. b d~ / /~ oo,,,~2~,t OiO' ,¢¢ OO ¢o0~ ¢ ~D ¢" 3~ ~o ~ 8~ ' '/¢ ' " , ,, 'LL: ¢-54-Z'b SPUD DATE: .= ELEV: L, · CALCULATED BY: ....... SHEET: _ ,: ii i iii 'i i i i j j ii i ., ii JMEA. VERTICAL DEPTH BEARING LATITUDE DEPARTURE , TOTAL AS. JSTA. ANGLE CUM; OF ' LATITUDE DEPARTURE ' SECTION ~THjDIST. COURSE TOTAL LOSS DEVIATI'ON NORTH SOUTH EAST' WEST ' NORTH 'I SOUTH EAST'" WEST' 7/0 a?o~ '~s :z.7 S, ~1 ~o' ~ , ~'~o l~o l~oo' ~t~ ~ ~~~? sj ~,,.~o ~ ~~ ,,, x~- . ~o~ ~o~ Ao~~ ' - , ' ~oq :~oo a~o' /~'? ~o~?~'~ ~9 ,~i dg~ ~ ~9~ , ~~ ~ ~3 ~'7 ~.~ )"' , , ~o 4~o~ oo 44~ ?~4~4~ ~, ) ~5 ~ ~% ~ t' ~4 .. I,/~-,~7~l~ ' ~ i .... . . ~oot'Zoo 3%o l~ '~~?? 9~ ~o~~t~g-"~ A ~o, , /o I~2~'3~ Io~o~ , . ~,~j ~? ~o~, ~ ~ ~ o~ ~o,{iq ~o ~,~s ~ ~ ~;° , .... ~ ~;s~ ~ ~1~ ~~"l'! _ . ,~ p ~'~ pi ~,,..I ~: ~~ I I... ~'~'~.. SPUD DATE: ELEV: ...... CALCULATED' BY: . SHF'-F_.T: .___.__ BEARING LATITUDE DEPARTURE .. TOTAL - AS. iMF--A.sTA. ANGLEI" VERTICAL DEPTH' .... CUM OF ' . LATITUDE [ ' DEPARTURE pTH DIST. COURSEI TOTAL LOSS DEVIATION NORTH I SOUTH EAST WEST , NORTH '"'SOUTH EAST ' WFST .- ,, , . -"LL: (~-~',,~-~,.~, SPUD DATE: ........ ELEV:.' CALCULATED BY:- ._ SHEET: . ,, " ,,.', ,- ' PD 4A (Rev. 5-63) Printed in U.S.A. 'Middle Ground Shoal (FI'~'L,D) _ KeBai SH~I/, OR, CO~PANY DRILI,] G R PORT EOR I)~/UOD I~%rD~G SEPTEMBER 30.~ 1967 w~L.o C- 3_4-23 Section :23 "'" ' REMARKS Surface 'Location: Conductor 6, 5.77'S & 0.81'W from center of leg 1, at 541.65'N & 1596.41'W from SE corner, Section 23, .. T8N, R13W, S.M. Elevation: Derrick Floor 106' (1ELLW) Sept 1967 _ 13 359 726 Spudded 12:01 a.m. 9'13-67. Ran in with 18-1/2" bit and drilled out cement from 359-369' conductor shoe at 369' Drilled to 390' with 18-1/2" bit. Drilled lo 473', gravel sloughing in hole. Circulated I conditioning mud for 5 hrs. Drilled to 726'. 14 726 1420i Drilled 15" hole to 1348'. Bowen bumper sub backed off. Top of fish · at 1151'. Ran in with overshot and recovered fish. Drilled 15" hole to· 1420'. 15 1420 .2035 Drilled 15" hOle to 2035'. Conditioned for logs. Ran DUAL INDUCTION - LATEROLOG~ RUN 1, 368' to 1588' AND BOREHOLE COMPENSATED SONIC LOG, RUN 1,..3_68 ' 't o .122.5_'.... 16-18~ 2035 2045 Drilled 15" 'hole to 2045'. Conditioned hole for ·casing. CEMENTED 10- 3/4" CASING AT 2007' WITH 1850 SACKS. Ran 10-3/4", J-55, 40.5f~ casing with shoe @ 2007.' and flow collar at 1963'. Cemented with 900 sacks ' class G cement-with 10% Bentonite followed by 300 sacks class G cement mixed with inlet water. Displaced with 1120 cu. ft mUd. Bumped ·plug with 1000 psi. No returns to surface. Ran 1" pipe outside 10-3/4" casing, found top at 302'. Pumped· in 500 sacks class G cement (118 pcf slurry) No cement to surface. 'Ran 1" pipe eutside of 10-3/4" casing, found' top cement at 105'. Cemented with 150 sacks class G cement. 19-20 2045 2552 Flanged up BOPE _RAN SPERRY SUN GYRO SURVEY FROM 37' TO 1950'. Tested BOPE, Hydril and rams with 1500 psi. Drilled out shoe at 2007', drilled 9-7/8" hole to 2552' mud 71 pcf. 21-30 ·2552 7041 Drilled 9-7/8" hole to 5680' lost one cone off bit ~10 Drilled on , ' iron with j.unk, sub from 5680-5693'. Drilled 9-7/8" hole to '7041', mud 72 pcf. .... FROM TO ' .. · · . '18-I/~' 359 390 · · 15 390 2045 10-3/4 2007 ' · '9-7/8 2045 7041 ' . · I ' · , DRILL PIPE 5" 19.5' ~ - ' ' ' ' '-.~ .' - ' '". ' ', ·."l, ' ~ I PD 4A (Rev. 5-63) Printed in U.S.A. Middle Ground Shoal , (COUNTY) SPIIILL OLr., CO~'JP..~ l~Olt PERIOD ENDII~G OCTOBER 21~ 1967 C-34-23 WELL. NO - Section 23 TSN. R13W (TOWt~SH., OR I~NCHO) DEPTHS FRO~4 I TO 7041 8927 6927 9628 9628 9642 9642 PBTD 9440 PBTD 9440 PBTD 9440 REMARKS Drilled 9-7/8" hole to 8927' mud 73 pcf Reamed 8813-8863' Drilled 9-7/8" hole to 9628' Reamed 8990-9020 9090-9106' 9280- 9226' 9320-9389' mud 74 pcf , , · Drilled 9-7/8" hole to 9642'. Conditioned hole for logs. Ran DUAL INDUCTION - LATEROLOG~ RUN 2~ 2004 TO 9615'~ COMPENSATED SONIC LOG, RUN 2~ 5609' TO 9609' HIGH RESOLUTION DIPMETER, RUN 1, 5618' TO 9618' AND FORMATION FACTOR - POROSITY LOGy RUN 1~ 5618- 9609'. Conditioned hole for casing. CEMENTED 7" CASING AT 9545' WITH 1100 SACK~ Ran 7" seal lock (34-124', 29#, N-80; 124-7453', 26#, N-80; 7453- 954.5', 29#, N-80) with float shoe at 9545' and self-fill differential collar at 9461'. Pumped in 100 cu. ft. fresh water ahead of 1100 sacks class G cement (117 pcf slurry) mixed with 1% CFR-2. Displaced with 2050 cu. ft. inlet water. Bumped plug with 2500 psi. Ran and energized casing hanger, seal assembly, tested ok with 3600 psi. Ran in with bit on 3-1/2" tubing. Found plug at 9437', cleaned out cement to 9440'. Displaced inlet water with diesel. Ran Schlumberger GAMMA RAY-COLLAR-CEMENT BOND LO.G.~ RUN 1~ 6030-943j0'. Ran 3-1/2" N-80 and J-55 tubing to 8360', set packer at 7127'· Installed and tested tree with 5000 psi. Perforated through tubing with 4 shots/ft. 8407-8439'; 8698-8728', 8799-8844', 8908-8932', 8939- 8949'; 8966-9088'; 9103-9164'; 9172-9250'; 9268-9278'; 9294-9419'. Placed well on production.. Released rig 5:00 p.m. 10-21-67. · CONDITION AT ~~~ PERIOD i HOLE. CASI.O SIZI~ DEPTH SET ' I 15" '390 [2045 10-3/4" ' 2007' 204s 7 ~ ~m[[~l~ 3 lt2" ~ · mz~, - t, tubing Form No. P--4 OIL ~ND ~$ ¢ONSERYATION ¢OMI~rrTIH~ #50-Z33-2004Z Effective: July t, 1964 LAND rl~'FI EE LESSEE'S MONTHLY REPORT OF OPERATIONS The followinff is a oorreot report of operatioT~s and prod~etion (i~el~di~ drillinff and prod~cin~ wells) for the month of ......... _0__c__t:__o__b__e__r ............... ~ .... 19_6__7__, _ ........................................................................... ./l ~e~ ff s address _ _ _ _~_ _~_ _ O_ _ _S. _e- _Y--e_~ ~ h-- ---A- -v- -~- -~- .u- -e- ........................... Oo m pany _ _ _ _S hf/]~://~O~ -~~, .... : ................ .............. _ .AB_ _ _q _h_ 9_ _r_ _a_ g_e_ , _ _ A_ _l_ _a_ _s_ _k_ _a_ _ _ _9_ _9_ _5. _O_ _l_ _ .......................... : ...... S i ~ n e d .......... Z L ~_ _ : /_ _ _~Z_ _ _~ :- : _ - - - -~- - ..... Phone __27_7_--_2621 ................................................................ ./l~ent's title __II[~_i.q ±on__ExploJ-~q~J-o~--F-~F=ineer ~o~ ~ SAS M Drill, Drill, Ran 3. Per fo: 8966- Place, Relea ~WP. [ RANG] ~S C134- ~.d 9~.7/8 ~.d ogt: c ,z/2'I :ate~ 4 )088~ 9 l we~l o md 9ig WELl NO. ho hen lng ~-ts )3- pr :00 ] )ATf, '437 83 m. I BARRELS OF 01L )642' lo . ran 9440 '. ,0'. S~t )ot~ 8407- 917 2- 9250 )no [0-21-67. gs Cu. FT. or GAS (In thousands) Cemented at 7127 '. 8698-8728 8-9278~ . 9 (]ALLONS OF (]ASOLINE P~ECOYERED 7" casii , 87 99-~ 94-9419 BARREIJ$ OF WATER (If none, so state) ~g at 95~ ;844' 8 REMARKS (If drilling, depth; if shu~ down, osuse; date and result of test for gasoline content of 5' with 1100 sacks. 08-8932' 8939-8949' NOTE.--There were ................................................ runs or sales of oil; ................................................ M cu. ft. of gas sold; runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless o~ the status of operations, and must be filed in duplicate with thc Division of Mines & Minerals by the 6th of the succeeding mont~L~ ~.htrV$f D directed. NOV 2 1967 01¥151ON OI~ MINES & MINERAk~ F'~,~rn No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE API ¢~50-133- 20041 Effective: July 1, 1964 LAND E] I=' F' I ~ ~ L~,,~ ,~ ADT. 18756 LESSEE'S MONTHLY REPORT OF OPERATIONS State ........ A___l__a__s__k__a_: ..................... B or o u g h ......... _K.e_n_._a_ '_z_ ....................... Field ......... _~_!_d_ d_ .!__o___._G ~_.o__u__n.._d___.S._.h..o. ~..1_ Tke followir~ff is a correo~ repor~ of operatior~s arid prod~e~ior~ (ir~cl~din~ drillinff and prod~cinff wells) for tl~e mor~t]~ of ........... _S__e_E_t__~_.m._b_~__r_ ............. 19_6_~___, ............................................................................ ........... ................................... .... ............ Pkor~e ......... _2_7__2__-___9__5__6__1_ .......................................................... d~en*' s ~t~le __D±v_Ls±on_Exp. loil:atton__Engineer GALLONS OF BARRELS o~t REMARKS SEC.~ oFAND~ TWP. RANGE WELL DaYs BARRELS OF OIL GRAVITY CU. FT. OF GA8 GASOLINE WATER (If (If drilling, del;th; if shut down, oau~e; No. l'ao~oc,. (In thousands) RECOVERED none, so state) date and result of te~t for g~oliae eont~nt o! SAS ]~GS (:-34-23 Spud, ted ]2:0] eom, 9-1.;-67. Drill[ed ]5" hole ~o 20.;5'. Ran I~gs. Ceme~ted 10-31/4" ~-asin at 1970' with 1940 sacks, Drill[ed c~'-7/8" hose to 7113'. , NOTE.--There were ................................................runs or sales of oil; ................................................ M cu. ft. of gas sold; ............................................................ runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operati_ons_~ and must succeeding monthaar~-e.,.,~ C with the Division of Mines & Minerals by the 6th of the ,x--r-... or~. ~r~e[ be filed in duplicate directed. .5 1567 DIVISION OF MINES & MINERAI.~ SHELL OIL::-COMPANY " 430 2TH AVENUE iANCHORAGE. ALASKA 99501 ., SePtember- 13, 1967 ~_ate-of Alaska 'Division344 S i:,ct h Of AvenueLands ~nchora~e, Alaska ,~tt~ntion I~. Pedro Denton Gentlemen: . Middle Ground Shoal Field State' of' Alaska Oil and Gas Lease ADL 18756 Pursuant to the terms 'of the captioned oil and gas lease, please advised that on. 9-I3~67, Shell Oil Company, as operator, spudded well 'C-'~-23 from Platform C.· The well will be d;~rcc-tiona!!? drilled to a bottom_ hole location in '-the SE/4 of Section ·23., T8N-R13W under the ca~'tioned lease. ' ' ' Yours Very truly, Cate Pivisiotl LaDd ~aRage~ 11, 1967 aha11 081 ~amy~ Ol~rat~ 2bamis R. Xi!rslmll. J~, l~e*..z'olmm su~ MEMORANDUM TO: J-- FROM: State .of Alaska DATE : SUBJECT: FORM SA- lB 50M t/67 MEMORANDUM' ~ ~ state, of Alaska DATE : SUBJECT.~ ~ F(~rm~_~ I SiA TE OF ALASKA (Other ins[ructions on reverse side) OIL AND GAS CONSERVATION COMMITTEE APPLICATION FOR,PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TYPE OF WORK DRILL I-~ DEEPEN [] PLUG BACK [--1 b. TYPE OF WELL . : SINGLE~-~ MULTIPLE O,LwELL [] WELLOAS [] OTHER ZONE ZON~ [] 2. NAME OF OPERATOR Shell 0±1 Company 3. ADDR~E~S OF OPERATOR - - 430 Seventh Avenue 4. LOCATION OF W~LL (Report.location clearly and in accordance with any State. requirements.*) At surface 'Leg-1' conductor 6': Leg I at 541.65'N & 1596.41 from SE corner. Sec'. 23, T8N, R13W, S.M. At proposed prod. zone Well to be drilled essentially vertical 14. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 17 miles NW from Kenai, Alaska ~o. mSTaNC~ fro,,, ~eoPOSED' lo. No. OF ACRES iN LEASE LOCATION TO NEAREST ~ROPERTY OR LEASE LINE, FT. 542' 5120 (Also to nearest drlg. unit line, if any) ~[~. DISTANCE FROM PROPOSED LOCATION* 19. PROPOSED DEPTH TO NEAREST WELL, DRILLING, COMPLETED, OR ~P,.,~ ~R, oN THIS ,-.~E, ~- -~-~OUUU' 9600 Effective: July 1, 1964 5. LEASE DESIGNATION AND SERIAL NO ADL 18756 6. IF INDIAN, ALLOTTEE OR TRIBE NAME None 7. UNIT AGREEMENT NAME None : 8. FARM OR LEASE NAME M*G,,S. 9. WELL NO, C'34- 23 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal ~11. SEC., T., R., M., OR BLK. AND SURVEY OR AREA _ 23, T8N, R13W 12. BOROUGH sHJ 13. STATE Kenai J Alaska 17.NO. OF ACRES ASSIONED TO THIS WELL 8O 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, GR, etc.) 22.' APPROX. DATE WORX WILL START* D.F. 106' Sept. 10, 1967 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT SETTING DEPTH QUANTITY OF CEMEN~ · 15" 10-3/4" 40.5 2000 ' 1200 sacks 9-7/8" 7" 26- 29t~ 9600 ' 1100 sacks IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal ts to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program, if an~ ~ ~-/ .~ 24. I hereby .~,~f~~_~ and correct. SIGNED / ~ ~ ~'L~ ~ ''" TITLE Division Exoloitation_ Enz_e DATE SiP (This space for Federal or State office use) PERMIT NO. ~7-' fi/ CONDITIONS OF APPROVAL, IF ANY: APPROVAL DATE ~ ..THOMAS R. MARSHAl. I;, Alaska DF& Gas *See Instructions On Reverse Side RECEIVED SE? 7,1967 01¥151ON OF MINES & MINERA~ 'C0NFJDENTIAL DRILLIN__G,.__CASI___N~,: A__N_p ~_L_OWp~ PREVENTION PROGRAM WELL C-34-23 MIDDLE GROUND SHOAL - PLATFORM "C" COOK INET, . Move rig over 24'7 subconductor 6, leg 1. Install. 20"., 2000 psi Hydril preventer. - 2' Drill 15" hole to 2000'~. Run logs. Run 2000'f o~ 10 3/4" 40.5# J-55 Seal-Lock casing. Cement with 1200 sacks AP1 cement,(900 sacks gel cement and 300 sacks neat cement.) ~, 3. Land casing and flange up 12" 3000 psi preventer stack consisting of Double Shaffer Gate and G.K. Hydril. 4. Drill 9 7/8" hOle to 9600'~. Run logs. Run 9600'~ of'7" 26# and 29# Seal- Lock casing. Cement with 1100 sacks API cement. 5. Perforate productive zone with 4 shots per foot. at selected intervals. 6. Run 3 1/2" 9.3# J-55 and N-80 EUE tubing string equipped with packers. Displace annulus above packers with inhibited Inlet water and displace tubing and annulus below packers with diesel oil. 'Set packers and place well on production. ., PRJ 8/30/67 RECEIVED SEP .?.1B67 DIVISION OF MINES & SHELL OIL 430 7TH ANCHORAGE, COMPANY AVENUE ALASKA 99501 September 6, 1967 PRIVATE & CONFIDENTIAL STATE OF ALASKA 3001 Porcupine Drive Anchorage, Alaska Attention: T.R. Marshall, Jr. Gent lemen: Enclosed for your approval is our Application for Permit to Drill well S.A.S.M.G.S. C-34-23 from our Platform "C". Also enclosed is our check i~~~~0~ for the filing fee. Very truly yours, R.D. Allen Division Exploitation Engineer Enclosures: Filing Fee Check (1) Application to Drill (3) Location Plat (3) Blowout Prevention Program (3) RECEIVED DIVISION OF MINES & MINERAL~
