The URL can be used to link to this page

Home My WebLink About200-099MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 4, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC M-29A PRUDHOE BAY UNIT M-29A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/04/2024 M-29A 50-029-21904-01-00 200-099-0 W SPT 7731 2000990 1933 1114 1114 1116 1114 115 357 349 347 4YRTST P Bob Noble 2/11/2024 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:PRUDHOE BAY UNIT M-29A Inspection Date: Tubing OA Packer Depth 287 2286 2263 2258IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240212153201 BBL Pumped:2.8 BBL Returned:2.4 Thursday, April 4, 2024 Page 1 of 1           MEMORANDUM State of Alaska Initial Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor �!j 3 i 0/&)W f� (t DATE: Tuesday, March 10, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. O M -29A FROM: Jeff Jones PRUDHOE BAY UNIT M -29A Petroleum Inspector 10'_3 2021 - 2017 - Ste: Inspector .2000990 Reviewed By:��++�� P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT M -29A Insp Num: mitJJ200228112013 Rel Insp Num: API Well Number 50-029-21904-01-00 Inspector Name: Jeff Jones Permit Number: 200-099-0 Inspection Date: 2/9/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min M -29A Type Inj O TVD 7731 - Tubing ''ma 10'_3 2021 - 2017 - 2012 .2000990 Type Test SPT Test psi 1933 IA 2657 2650 2661 - 2661 2662 Pumped: r IBBL Returned: OA 55 60 _ 62 - 63 (Interval I 4YRTST IP/IF� P Notes: This data is well head pressure readings from third 60 minutes of 180 minute test as noted on report mit11200228110857. This is a retest of previously conducted inconclusive test. Tuesday, March 10, 2020 Page 1 of I MEMORANDUM TO: Jim Regg I \Clr 1 3I q (-1a0 P.I. Supervisor FROM: Jeff Jones Petroleum Inspector Well Name PRUDHOE BAY UNIT M -29A IInsp Num: mitJJ200228110857 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, March 6, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. M -29A PRUDHOE BAY UNIT M -29A Ste: Inspector Reviewed By: P.I. Supry 56r— NON-CONFIDENTIAL Comm API Well Number 50-029-21904-01-00 Inspector Name: Jett Jones Permit Number: 200-099-0 Inspection Date: 2/9/2020 - Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 71. -Type lnj O -TVD 7731 - Tubmgl 1982 1991 I'Jv'_ 'OIR 2019 - 'o'1- -Type Test sPT Test psi 1933 - IA 44 z597 _ 2599 - rol4 2620 - zeas 3.a BBL Returned: 3.a OA n 30 3s 4YRTST P/F I Notes: -32 deg. ambient, well injecting Q 65 deg. diesel was heated to 65 deg. Total test time 180 minutes, shown as three 60 minute tests: I st 60 min. test witnessed - inconclusive; 2nd 60 min. test not witnessed - operator report indicates inconclusive; 3rd 60 min. test witnessed - pass csee report sysJ1200228112013). I well inspect -R, -no exceptions noted. T<S- ws due Sk..G 2u tq , we* stud- t.i u.�LAt ime J4AIVI a(} z0 Friday, March 6, 2020 Page I of I Wallace, Chris D (CED) From: AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com> Sent: Monday, February 10, 2020 5:42 PM To: AK, GWO Well Integrity Engineer, AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W, AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr, AKOpsProdEOCTL, Infanti, Samuel; Nottingham, Derek, Stechauner, Bernhard; Wallace, Chris D (CED) Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity, AK, GWO SUPT Well Integrity, AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R, Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Injector M-29 (PTD #2000990) AOGCC MIT -IA Passed All, M-29 (PTD #2000990) was put on injection and made Under Evaluation on 01/14/19 after lapsing on a required 48 month AOGCC MIT -IA. An MCX injection valve was set on 01/30/20 and tested on 02/03/20. An AOGCC MIT -IA passed on 02/09/20. The well will now be classified Operable. Please respond with any questions. Ryan Holt Well Integrity BP Global Wells Organization -Alaska Office: 907-659-5102 Fr6m: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: esday, January 14, 2020 5:39 PM To: AK, OPSEOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2Fa " OTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@*r101 m>; AK, OPS GC2 Wellpad Lead <AKOPSGC2Wel[pad Lead @bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp. m>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWeliPadDFTN2@bp.c >; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWeIIPadLV@bp.com>; AK, S Well Pad MN <AKOPSWeIIPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWeIIPadRJ@bp.com>; AK, OPS LL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWeliPadSW@bp.com>; AK, OPS W PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWeliPadZ@bp.com>; Ak, Ops West Area <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES G est Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Infanti, uel <samuel.infantil@bp.com>; Nottingham, Derek <Derek.Nottingham@bp.com>; Stechauner, Bernhard <Bernha Stechauner@bp.com>; 'chris.wallace@alaska.gov' <chris.wa I lace@a laska.gov> Cc:'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&C DWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO T Well Integrity <AKDCWeIIlntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information akgwowellintegritywe@bp.com: P6QnJ-Zq Regg, James B (CED) P T6 BUD f l y From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, January 30, 2020 3:24 PM j� p 1 To: Regg, J mes B (CED) f 3a`Z�Za Subject: RE: WAG Injector M-29 (PTD #2000990) Overview and Plan Forward Mr. Regg, Below is a 3 month TIO plot. Slickline is currently on the well to replace the MCX. Once they get the MCX replaced and tested, performing a State Witnessed MIT is the top priority. Andrew Ogg Well Integrity Engineer BP Global Wells Organization —Alaska Office: 907-659-8110 From: Regg, James B (CED) <jim.reggCa@alaska.gov> Sent: Thursday, January 30, 2020 9:43 AM To: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Subject: RE: WAG Injector M-29 (PTD #2000990) Overview and Plan Forward Send Tio pressure plot. If other options for keeping the skid warm have been exhausted the well can remain online. Jim Regg Supervisor, Inspections AOGCC 333 W.7h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: AK, GWO Well Integrity Engineer <AKGWOWeIISiteEnginee@bp.com> Sent: Wednesday, January 29, 2020 7:53 AM To: Regg, James B (CED) <iim.reggc@alaska.eov> Cc: Wallace, Chris D (CED) <chris.waIlace @alaska.gov>; AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com>; AK, GWO Projects Well Integrity <AKDCPro iectsWeIII ntegrityEngineer@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritvwe@bp.com>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bav@alaska.gov>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Subject: RE: WAG Injector M-29 (PTD #2000990) Overview and Plan Forward Mr. Regg, Attached is a copy of the M-29 Test Report. Responses to your questions are in red below. Please let me know if you have any more questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 From: Regg, James B (CED) <iim.regg@alaska.gov> Sent: Tuesday, January 28, 2020 2:58 PM To: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Cc: Wallace, Chris D (CED) <chris.waIlace Ca) alaska.gov>; AK, GWO SUPT Well Integrity <AKDCWelllntegritvCoordinator@bp.com>; AK, GWO Projects Well Integrity <AKDCProiectsWeIIIntegrityEnginee r@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe. bay@alaska.gov> Subject: RE: WAG Injector M-29 (PTD #2000990) Overview and Plan Forward So as of right now M-29 does not have passing MIT and SVS test. Not clear from your overview if the well's entire SVS was tested or just the SSSV. Send test report. Also unclear if the well is currently online or shut in. It is online. If online what is the basis for BP's internal waiver? Initially, it was to keep the well warm until slickline's arrival to ease the task of replacing the MCX since we have the 14 day allotment. This then became coupled with keeping the MI skid warm due to the surface temperature dropping. Currently, M-29 is the only well on M -Pad that is on MI. If it was SI then the heat that is generated by the injector would not be available for keeping the skid warm and would expose the skid to potential leaks and halon dumps - if it got too cold inside the skid. There are other ways to keep the skid warm but we left the well online because we were working with a 14 day clock and the assumption slickline would be on location soon Or is the well online until 1/30 when the 14 day clock (install and successfully test SSSV) expires? With hopes of outside warming conditions and slickline slated as a priority to move onto the well first chance the well has been left online. It will be SI if the 14 day limit is reached. You mention 14 days to complete a SSSV test. Is that because the failure was its inability to hold dP? Yes, the well was left online to keep warm for slickline to replace the failed SSSV. As described above, the thought being they would be on the well in short order. Was AOGCC notified in response to the failed SSSV test on 1/16? It was a witnessed test by Adam Earl. No other notification was made as with normal practices. Sent via the Samsung Galaxy S8 Active, an AT&T 5G Evolution capable smartphone -------- Original message -------- From: "AK, GWO Well Integrity Engineer" <AKGWOWeIISiteEnginee@bp.com> Date: 1/28/20 1:59 PM (GMT -09:00) To: "Regg, James B (CED)" <iim.regg@alaska.gov> Cc: "Wallace, Chris D (CED)" <chris.wallace@alaska.gov>, "AK, GWO SUPT Well Integrity" <AKDCWelllntegrityCoordinator@bp.com>, "AK, GWO Projects Well Integrity" <AKDCProiectsWelllnteerityEngineer@bo.com>, "AK, GWO Well Integrity Well Information" <a kewowe l I i me eritywe P b p. co m> Subject: WAG Injector M-29 (PTD #2000990) Overview and Plan Forward Mr. Regg, M-29 (PTD # 2000990) is a WAG injector that had recently been on produced water injection from 03/24/19 until it was shut in on 06/18/19. While shut in, the well became due for its four year State witnessed MIT -IA on 07/31/19 and was made Not Operable on 08/01/19 for tracking purposes. On 10/30/19 the well was made Under Evaluation for a temporary flowback after the well had been identified as a potential injector to producer conversion. The temporary flowback was completed on 11/03/19 and the well was re-classified back to Not Operable on 11/04/19 for tracking purposes. On 01/14/20 the well was swapped from PWI to MI and re-classified as Under Evaluation to ensure a state witnessed MIT -IA would be performed once on stable injection. On 01/15/20 while trying to put the well on injection, an ice plug was discovered in the production tubing which required a thaw job before putting the well on injection. On 01/16/20 the well was put on injection, but subsequently failed a SSSV test. The state witnessed MIT -IA was originally scheduled for 01/21/20 in BP's internal system, but was pushed out until 01/25/20 because Slickline was scheduled to arrive on 01/21/20 to troubleshoot/replace the SSSV. Operational issues on other wells hindered Slickline from meeting the original schedule, but Slickline re -scheduled the job to troubleshoot/replace the SSSV after the State witnessed MIT -IA on 01/25/20. On 01/25/20 the State witnessed MIT -IA was cancelled because inclement weather would not allow work to proceed in accordance with BP's cold weather working policy. A risk assessment was performed and an internal variance to the cold weather working policy was completed and a State witnessed MIT -IA was performed on 01/27/20 which was deemed inconclusive by the State Inspector. Due to the current weather forecast, it does not appear that the SSSV will be replaced before the required 14 day timeline and the well will get shut in. BP plans to re -test the well once the weather is in compliance with BP's cold weather working policy, the SSSV has been replaced and passed a SSSV test, and the well is back on stable injection. Please respond if in conflict with this plan. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 PBU M-29 (PTD 2000990) 30day TIO Pressures Plot 1/30/2020 YAA:IF7i -4- Th, -0- IA - +OA i OOA ■ 01 . Ma ♦ ".Oa OPE ♦ Tn . iempe�enirc Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, January 14, 2020 5:39 PM To: AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW, AK, OPS WELL PAD W, AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, Infanti, Samuel; Nottingham, Derek, Stechauner, Bernhard; Wallace, Chris D (CED) Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R, Tempel, Joshua; Worthington, Aras J Subject: UNDER EVALUATION: Injector M-29 (PTD #2000990) Return to service All, M-29 (PTD #2000990) was made Not Operable on 11/04/19 post temporary flowback after not being on injection at the time of regular 48 month AOGCC MIT -IA. An MCX injection valve was installed on 01/02/20. The well will now be classified UNDER EVALUATION. Plan Forward 1. Operations: Put on injection 2. Well Integrity: Perform AOGCC Witnessed MIT -IA once thermally stable Please respond with any questions. Ryan Holt Well Integrity BP Global Wells Organization - Alaska Office: 907-659-5102 Froril. K, GWO Well Integrity Engineer Sent: Mo ay, November 4, 2019 10:41 AM To: AK, OPS E Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2Facility bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.co K, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWeIIPadDFTN2@bp.com>; A S Well Pad HUQ <AKOPSWeIIPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWeliPadLV@bp.com>; AK, OPS Wel MN <AKOPSWeliPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD OPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWeliPadSW@bp.com>; AK, OPS WELL PAD W <A WELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWeliPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWes aTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Op r <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Infanti, Samuel <samuel.in a @bp.com>; Nottingham, Derek <Derek.Nottingham@bp.com>; Stechauner, Bernhard <Bernhard.Stechauner@bp.c >;'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> MEMORANDUM State of Alaska Depth Pretest Alaska Oil and Gas Conservation Commission Well DATE: Tuesday, January 28, 2020 TO: Jim Regg�ppp""" j r ee, -2/`149w SUBJECT: Mechanical Integrity Tests P.I. Supervisor 1 I BP Exploration (Alaska) Inc. 2030 2027 1 M -29A FROM: Matt Herrera PRUDHOE BAY UNIT M -29A Petroleum Inspector IType Test SPT See: Inspector 1933 Reviewed By: 2701 - 2699 2700 2702 P.I. Supry jr-v— NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT M -29A API Well Number 50-029-21904-01-00 Inspector Name: Matt Herrera Permit Number: 200-099-0 Inspection Date: 1/27/2020 Insp Num: mitMFH2O0128074720 Rel Insp Num: Tuesday, January 28, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well M -29A ' Type Inj G 'TVD 7731 ' Tubing 2028 2030 2027 1 2031 2071 PTD 2000990 IType Test SPT Test psi 1933 IA 13 2701 - 2699 2700 2702 BBL Pumped: 3.9 BBL Returned: 3.3 OA s 44 44 44 as Interval 4YRTST P/F I Notes: IA Pressure test to 2700 PSI Per Ops. Unstable IA pressure deemed test inconclusive ✓ Tuesday, January 28, 2020 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Nnv 7 5 kinin 1. Operations Performed ' Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ O eratiol` Suspend ❑ Perforate m Other Stimulate ❑ 1lpp11 Alter Casing 11 Chang e,A�pQDQQ ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to DnII Number. 200-099 3. Address: P.O. Box 196612 Anchorage, AK99519-6612 Stratigraphic ❑ Service 21 6. API Number: 50-029-21904-01-00 7 Property Designation (Lease Number): ADL 028260 & 028282 8. Well Name and Number: PBU M -29A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 10773 feet Plugs measured 10315 feet true vertical 9039 feet Junk measured 10740, 10750 feet Effective Depth: measured 10315 feet Packer measured 8573 feet true vertical 8705 feet Packer true vertical 7731 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 32-112 32-111 1490 470 Surface 2662 13-3/8" 31-2693 31-2688 5020 2260 Intermediate 9493 9-5/8" 29-9522 29-8564 6870 4760 Liner 813 7" 8720-9533 7859-8574 8160 7020 Liner 2124 2-7/8" 8649-10773 7797-9039 13450 13890 Perforation Depth: Measured depth: 9820-10761 feet True vertical depth: 8731 -9027 feet Tubing (size, grade, measured and true vertical depth) 7" 26# x 5-1/2" 17#, L-80 26-8720 26-7859 Packers and SSSV (type, measured and 5-1/2" TIW Packer 8573 7731 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Pdortowell operation: Shut In 0 1200 Subsequent to operation: Shut In 0 1100 14. Attachments: (required per 20 roc 25.070.25 on, a 25.283) 15. Well Class after work: Daily Report of Well Operations 9 Exploratory ❑ Development ❑ Service m Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ I GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SundryNumber or N/A if C.O. Exempt: WA Authorized Name: Infanti, Samuel Contact Name: Infanti, Samuel Authorized Title: Petroleum Engineer Challenger Contact Email: samuel.infantilgbp.00m Authorized Signature: Date: If 5.I of Ql Contact Phone: +19075645676 Form 10404 Revised 04/2017 t� l� i m64';1- -xkL*H'? A MSNE✓NOV 2 61019 Submit Original Only Daily Report of Well Operations PBU M -29A ACTI V ITV nATF n, ,.*....... 10/29/2019 CTU #8 1.75" CT Job Scope: Adperf and N2 lift MIRU CTU. MU & RIH w/ HES 2.20" Logging Carrier & 2.24" JSN. Tag CIBP down at 10293'. Log from compression up to 8400'. Flagged pipe at 10230 Pooh. Log data showed a +35.5' correction making corrected EDP at flag = 10254.57 and top of CIBP 10331.53. Make up perf gun #1. RIH ***Job Continued on 10/30/19*** CTU #8 1.75" CT Job Scope: Adperf and N2 lift Continue Rih w/ Perf Gun #1. Tag CIBP & Correct Depth. Puh & Perforate Interval 10235' - 10266'. Pooh. All shots fired, ball recovered. MU & RIH w/ Perf GunTag CIBP & Correct Depth. Puh & Perforate Interval 10116'- 10147'. Pooh. All shots fired, ball recovered. MU & RIH w/ Perf Gun #3. Correct Depth. Pub & Perforate Interval 9876' - 9907'. Pooh. All shots fired, ball recovered. MU & RIH w/ Perf Gun #4. Tag CIBP & Correct Depth. Puh & Perforate Interval 9826'- 9857'. Pooh. All shots fired, ball recovered. Perform Weekly BOP Test. Ref Log Depths: 9820'- 9851' 9870'- 9901' 10110'- 10141' 10229' - 10260' 10/30/2019 ***Complete*** FREE = 6-3/8" CAW WELLHEAD= McEVOY ACTUATOR= BAKERC KB. ELEV = 56.11' BF. ELEV = 27.82' KOP= 3189' Max Angle = 103' @ 9917' Datum MD = 10581' Datum TVD = 8800' SS 68#, 1 7" TBG, 26#, L-80-NSCC, .0383 bpf, D = 6.276" I Minimum ID = 2.31" @ 8654' 2-7/8" X NIPPLE = 4.892" 1 8498' TOP OF 7" LNR8720' 9-5/8" CSG, 47#, L-80-BTRS, ID = 8.681" 9522' I TOP OF 7' BAKER WHIPSTOCK I ID = 6.184" PERFORATION SUMMARY REF LOG: SPERRY MWD/GR ON 07/16/00 ANGLE AT TOP PERF: 840 @ 9820' Note: Refert0 ProducOon DB for historical pert data SIZE I SPF INTERVAL O NS z SHOT SQZ 2 6 9820-9851 O 10/30/19 0429/15 2 6 9870-9901 O 10/30/19 2 6 10110-10141 O 10/30/19 2 6 10145-10170 O 04/18/03 2 6 10229-10260 O 10/30/19 2 6 10245-10270 O 04/18/03 2 6 10350-10375 C 04118/03 2-7/8" 10696-10761 SLTD 07/21/00 GE 125 M=29ASAFETY NOTES: H2S READINGS ppm WHEN ON MI** WELL QURFESASSSV WHEN ON MI *** WELL ANGLE > 70° @ I /Z" U I IS AA SLD SLV , ID = 4.562' 5/8" X 5-1/2" TIW HBBP PKR 1/2" OTIS X NP, ID = 4.562" 12" NS SCOOP GUIDE W/PTSA (07/( 72" BKR DEPLOY SUB, D = 3.00" 718"X NP, D = 2.31" 1/2" OTIS XN NIP, D = 4.455" TIW SEAL ASSY W/O SFALS 7 " MILLOUT WINDOW (M -29A) 9533' - 9540' CIBP 10740' FISH: MLL C13P (0721/19) ` FISH -(3)1-1/16' 2-7/8" SLTD LNR, 10898' - 10]81' ROLLERS 6.16#, L-80, .0058 bpf, D 2-7/8" LNR, 6.16#, L80 STL, 10773' .0058 bpf, D = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 02 "9 N48E INITIAL COMPL AS INJECTOR 0423/18 GJB/JMD ADDED INSERT W/RQ NP (5/2/16) 07/18/00 JCM CTD SIDETRACK (M -29A) 07/22/19 JDM/JMD PULL INSERT, SETSCOOP GUIDE 01/18/12 TMN/JMD ADDED H2S SAFETY NOTE 0722/19 JDM/JMD SETCBP & SET FISH 0721119 0422/15 RB/PJC TREE C/O 08/12/19 DD/JMD CHANGED BF ELEV & 9-5/8" CSG DEPTH 0429/15 RJK/PJC PULL INSERT 11/04/19 TFA/JMD ADPERFS 10/30/19 08/09117 JMD MINOR CLEAN UP PER TALLIES PRUDHOE BAY UNIT WELL: M -29A PERMIT No: 2000990 API No: 50-029-21904-01 T11 N. R1 2E, 2267' FSL & 605 BP Exploration (Alaska) Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Monday, November 4, 2019 10:41 AM To: AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z, Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr, AKOpsProdEOCTL; Infanti, Samuel; Nottingham, Derek; Stechauner, Bernhard; Wallace, Chris D (CED) Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis 1; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: NOT OPERABLE: Injector M-29 (PTD #2000990) Temporary flowback complete M9 M-29 (PTD #2000990) was made Under Evaluation on 10/30/19 to put on production for a temporary flowback through a portable test separator. The temporary flowback was completed on 11/03/19. The well will now be classified back to Not Operable. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 From: GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: We day, October 30, 2019 8:39 AM To: AK, OPS EO ecialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2Facility0 bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2Field PTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.coIn • K, OPS GC2 Wellpad Lead <AKOPSGC2WeIIpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad MN <AKOPSWeliPadMN@bp.com>; Ak, West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL<AKOPSPCCEOCTL@bp.com>; anti, Samuel <samuel.infantil@bp.com>;'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; Atkinson, Tim <Tim.Atki n@bp.com> Cc: AK, GWO Completions Well Integrity <AKDCWLComple . sSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Inte 'ty<AKDCProjectsWelllntegrityEnginee r@bp.com>; AK, GWO SUPT Well Integrity<AKDCWellintegrityCoordinator@bp.c >; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKO FWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; iel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dem pseyl@bp.com>; Hibbert, Michael <Michael.Hibber BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obr witch, Beau Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Wednesday, October 30, 2019 8:39 AM To: AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad MN; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, Infanti, Samuel; Wallace, Chris D (CED); Atkinson, Tim Cc: AK, GWO Completions Well Integrity, AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (CED) Subject: UNDER EVALUATION: Injector M-29 (PTD #2000990) Temporary flowback through portable test separator All, M-29 (PTD #2000990) is a mechanically sound WAG injector that was made not operable on 8/01/2019 for lapsing on its 4 year AOGCC MIT -IA. The well has been identified as a potential producer conversion and scheduled for a temporary flowback through a portable test separator later this week. A this time the well is reclassified as Under Evaluation for tracking purposes with the clock set at 14 days. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS A� AM 1 G in,n 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shut(i` r1"r s"'� -M x�> Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved rogram Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Mill CIBP / Set CIBP ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Dnll Number. 200-099 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 0 1 6. API Number: 50-029-21904-01-00 7. Property Designation (Lease Number): ADL 028260 8 028282 8. Well Name and Number: PBU M -29A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 10773 feet Plugs measured 10315 feet We vertical 9039 feet Junk measured 10650, 10740 feet Effective Depth: measured 10315 feet Packer measured 8573 feet true vertical 8705 feet Packer true vertical 7731 feet Casing: Length. Size: MD: TVD: Buret: Collapse: Structural Conductor 80 20" 32-112 32-111 1490 470 Surface 2662 13-3/8" 31 -2693 31 -2688 5020 2260 Intermediate 9493 9-5/8" 29-9522 29-8564 6870 4760 Liner 2124 7" 8720-9533 7859-8574 8160 7020 Liner 2124 2-7/8" 8649-10773 7797-9039 13450 13890 Perforation Depth: Measured depth: 10145 - 10761 feet True vertical depth: 8690-9027 feet Tubing (size, grace, measured and true vertical depth) 7" 26# x 5-112" 17#, L-80 26-8720 26-7859 Packers and SSSV (type, measured and 5-1/2" TIW Packer 8573 7731 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In 0 1950 Subsequent to operation: Shut -In 0 1800 14. Attachments: (required per 20 MO 25,070 25 1371, s 25 2a1) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sun dry Number or N/A if C.O. Exempt: WA WA Authorized Name: Stechauner, Bernhard Contact Name: Stechauner, Bernhard Authorized Title: FS d PE Contact Email. Befnhard.StechaunerObp.mm Authorized Signature: _ Date: 8/J4/ 19 Contact Phone: +1907 564 4594 Foran 10-404 Revised 0412017 '00!/ e '� mp.I. "941 RBDMS.�4AUG 15 Y019 Submit Original Only Daily Report of Well Operations PBU M -29A ****WELL S/I ON ARRIVAL SWCP 4518***(profile mod) RAN 4-1/2" X -EQ -PRONG S/D @ 2076' SLM (2098' MD) PULLED 4-1/2" SPIDER SSSV(ser# = RS -01) FROM 2076' SLM DRIFTED TO 7" INSERT W/6.05" GAUGE RING TAG @ 2074' SLM PULLED 7" INSERT FROM 2074' SLM (2098' MD) DRIFTED W/5 1/2" GR, 5 1/2" BAIT SUB, PTSA STINGER DRIFT TAGGED DEP SLV @ 8632' SLM (8649' MD) SET NORTHERN SOLUTIONS SCOOP GUIDE FOR 5 1/2" TBG W/RETRIEVABLE SEAL GUIDE @ 8632' SLM PULLED SEAL GUIDE FROM 8632' SLM DRIFTED 5'x 2.25" BAILER TO DEV @ 9746' SLM 7/9/2019 'WELL LEFT S/I PAD OP NOTIFIED ON DEPARTURE*** CTU 9 1.75" CT. Job Objective: Mill CIBP/Set CIBP MIRU CTU. RIH w/ Baker 1.69" Milling BHA w/ 2.30" Junk Mill. Pressure up IA to 1000psi. Perform Injectivity Test. 5 -bpm @ 790psi. Tag high at 10370'. Mill thru with no issues. Drytag CIBP at 10644'. Flag Pipe. Begin to mill CIBP. 7/20/2019 ***Continue Job on 7/21/19 WSR*** CTU#9 1.75" CT. Job Scope: Mill CIBP / Set CIBP Attempt to mill CIBP. Unable to maintain steady motorwork, immediate stalls. Pooh. Make up and RIH with 2.300" junk mill and 2.125" motor. Mill CIBP at 10646 CTM and push to 10740 CTM. Post milling injectivity test 909psi @ 5 -bpm for 10 minutes. POOH. Make up and RIH with 2-7/8" CIBP. Correct depth at flag. Set Top of CIBP at 10315'. Pooh. Perform Final Injectivity Test. Tbg pressured right up to 2000psi and had to shut down the pump. In 10 mins Tbg bled from 2043psi to 1902psi. Close to zero injectivity into upper perfs. Lay in Diesel Freeze Protect from 2500'. 7/21/2019 ***Continue Job on 7/22/19 WSR*** CTU#9 1.75" CT. Job Scope: Mill CIBP / Set CIBP Lay in Diesel Freeze Protect from 2500'. Rig Down CTU. 7/22/2019 ***Job Com lete*** TREE = 6-M' CNV WELLHEAD=____ ACTUATOR_= KB. ELEV= McEVOY BAKER C 56.11' BF. ELEV =_____27.82' KOP = 3189' Max = 103` 9917' Datxn MD= 10581' DabmTVD = 880(y SS 113-3/8' CSG. 68#, L-80-BTRS. D = 12.415- I Minimum 10 = 2.31" 2-7/8" X NIPPLE I TOP OF 2-7/8' LNR I 5-12' TBG, 17#, L-80-BTRS, .0232 bpf, D = 4.892' 8719' 9 -SW CSG, 47#, L-80-13 ID = 8.681' 9522' TOP OF 7' BAKER WHPSTOCK 9530- 17- LNR 29#. L-80..0371 bpf. D = 6.184' 1 ?S REQUIRES NGS GE 125 M -29A ppm WHEN ON MI WELREADL A SSSV W WHEN ON MI ••` WELL ANGLE> 70° @ 9744' --- 2098' 1-17. OTIS SSSV LANDNG NP, D= 5962- NS SCOOP GUDh W/P ISA 8654' 1 -i2 -78"X MP, D=2.31' 17' TNV SEAL ASSY W/O SEALS I 7 " MILLOUT WINDOW (M -29A( 9533' - 9540' I BKR COP (0721/191 10740' FISH: MILL CIBP(0721/19) ? FISH -(3)1-1/16' 2-7/8' SLTD LNR, 10696'- 10761' ROLLERS .0058 bpf, D = 2.44' 2-7/8- LNR 6.16#, L80 STL, 10773' .0058 bpf, D = 2.441" DATE REV BY PERFORATDN SUMMARY DATE I REV BY I COMMENTS REF LOG: SPERRYMWDrGR ON 07/16/00 INITIAL COMPL AS INJECTOR ANGLE AT TOP PERF: 89" @ 10145' Note: Re%rto Pmdoction DB fortistorical perfdata SIZE SPF INTERVAL OpmSqz SHOT SOZ 2 6 10145 -10170 O 04/18/03 08109/17 JMD 2 6 10245-10270 O 04/1883 2 6 10350 -10375 C 04/18/03 2-78" 10696-10761 SLTD 0721/00 ?S REQUIRES NGS GE 125 M -29A ppm WHEN ON MI WELREADL A SSSV W WHEN ON MI ••` WELL ANGLE> 70° @ 9744' --- 2098' 1-17. OTIS SSSV LANDNG NP, D= 5962- NS SCOOP GUDh W/P ISA 8654' 1 -i2 -78"X MP, D=2.31' 17' TNV SEAL ASSY W/O SEALS I 7 " MILLOUT WINDOW (M -29A( 9533' - 9540' I BKR COP (0721/191 10740' FISH: MILL CIBP(0721/19) ? FISH -(3)1-1/16' 2-7/8' SLTD LNR, 10696'- 10761' ROLLERS .0058 bpf, D = 2.44' 2-7/8- LNR 6.16#, L80 STL, 10773' .0058 bpf, D = 2.441" DATE REV BY COMMENTS DATE I REV BY I COMMENTS 028489 N -18E INITIAL COMPL AS INJECTOR 0423/18 GJB/JMD ADDED NSERTw/RO NP (52116) 07MSI00 JCM CTD SIDETRACK 29A) 0722119 JDWJMD PULL INSERT, SET SCOOP GUIDE 01/18/12 TMN/JMD ADDED H2S SAFETY NOTE 0722119 JDWJMD SET CIBP & SET FISH 0721119) 0422/15 RB/ PJC TREE C/O 08/12/19 DD/JMD CHANGED BF ELEV & 93/8' CSG DEPTH 0429115 RJK/PJC PULL INSERT 08109/17 JMD MINOR CLEANUP PERTALLES BP Exploration (Alaska) Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, August 1, 2019 10:32 AM To: AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ AK, OPS Well Pad MN; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, Stechauner, Bernhard; Wallace, Chris D (CED) Cc: AK, GWO Completions Well Integrity, AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity, AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A, Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (CED) Subject: NOT OPERABLE: Injector M-29 (PTD #2000990) Will not be brought online for 4 year AOGCC MIT -IA Attachments: M-29A.pdf 03 Injector M-29 (PTD #2000990) was due for its 4 year AOGCC witnessed MIT -IA on 7/31/2019. The well is currently offline and will not be brought online until after the GC2 tar. At this time the well is reclassified as Not Operable for tracking purposes. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 bon 6 C O r 0 U)u /L © CW7�Z V Y > %it to N X tp L N to Q� J� . a o drY _• H v Y s C O Z p ~ r le o E u aJ EYO 4 a c 0 O` 5 w a1 fa Q) co >- a Q d A 0 O '� II^^ N N V) Ill NLO in in ra O N L m V. r r r r r Y V Y H I- 0 G > C > > C L9 C C COM t0 C C ] '-^ _C C C c V) . N N N co 7 N r- r N co co C aJ > Q1 Z a c o a _ Z < a o E o > , 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 co al u s CT a J J J J J J J J J J J J J J J >. W W W W W W W W W W W W W W W OOa C ca O O F LL LL LL U. U. LL LL. LL LL LL LL LL LL LL LL v) a) E -o N Q J J J J J J J J J J J J J J J Q 0CU C CU :1) -' < Q Q Q Q Q Q Q Q Q Q Q Q Q Q C C -.7) ZZZZZZZZZZZZZZZ U v, `^ u O 07 QLL LL LL LL LL U. LL U. LL LL LL LL LL LL LL a C Q D N _v O 9 4- 0E N E ai a o p Z ovm c C y a O O O O O O F- F- > > C Q1 b O .- E c.) ,-- 00000 0 0 z F- F- < cu C V > U 0 u. 0 0 0 0 0 0 O u_ 0 Ce 7 7 2 J O wdmmmmm m CewadcJ ° re V V O V y2 m, H H F- F- F- F- J a W n iJ d- zzzzzz00 pJ < 2wwwww uJO G1 U > wwwww w a PI V ti n _, 0 0 0 0 0 0 w ar 0 0 N 0 1.1 C x p z m I ..% 5-. t u 0 ct re ce ce iz ee w ee ce J i os i s a J 0 0 0 0 0 0 0 0 0 J J J J J 2 2 2 2 2 2222 S z --1 01 N N W W W W W W W W W La } } } } } } } } } } } } } } } z MI QQQQQQQQQQQQQQQ sr 2mmmmmm mmmmmmmmm u z' 000000 000000000 V' 0 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 a J 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 v U..o EX Q= X Ct Q' Q' Q' d' 2 C' d' Ce CC C4 C a Cl. a a a a a a a a a a a a a c tuLY X o 0 `.-:� ,� W � CO M h T, V) V CO � O T co �p O V) O -Q V) 0 N- 0 O) CD co CD co CO N CO N N CO a 00 0 0r- 0 0 0 0 .- 0 0 0 ,- 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 MUM w 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 _ m Ili��i 8 5 U 0 2 0 2 2 U 2 U 0 2 0 N 0 N to ,—. U O u) t0 CO N CO fn CO c0 U m M m „,A C Q '- } > > > X > X > } m N CO Ce 51 cc UJ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m no a o Or 0 '- V) 0 0 e- .- m- 0 0 0 0 0 CO u l0 0 0 0 0 0 O O 0 0 0 0 0 0 0 0 o C r 0 CO N 6LO CO O O) LO C) O �-' < O O) V) V41. co o V) M M N It) CO 111 - 0) M V N V) CO VO V) N V) O) N To 15 N O N 0 O M N M M N 0 0 4'' > N -- NCNNNNN N NNNNNNNN -- CO I-7 (4) O) O) O) OT O ) ) CO 0 O ) O) ) OT) O) E C p N N N N N N NNN NNNNNN 0 01 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 C .... O O O O o O O o O o o O O O O c C in V) V) V) )f) V) V) V) V) It) It, N )P) V) V) +,, 44' CO r CO•44C Q -0 w CU C=9 �cc F E k.,CU C E o .°D o m =CID W Y 8 1 a E 'I Zr 0 M 4- O a Q �,L o 0 v v 0 0 N ETa a) C N 0v/ e0 n J ^ M N O N r M a+ CO N O a Q N w O o o m C7 -) a 2 C= V) 0 Z N -o Q y F- a a O 00 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,July 14,2015 P.I.Supervisor <\ (f(I Z(t5T SUBJECT: Mechanical Integrity Tests l ` BP EXPLORATION(ALASKA)INC M-29A FROM: Chuck Scheve PRUDHOE BAY UNIT M-29A Petroleum Inspector S `J `I COOED rF Src: Inspector Reviewed By: P.I.Supry J Cf— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT M-29A API Well Number 50-029-21904-01-00 Inspector Name: Chuck Scheve Permit Number: 200-099-0 Inspection Date: 7/11/2015 Insp Num: mitCS150712060118 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min TypeTubing Well M-29A T e In' W'TVD 7731 _ 733 - 749 - 740 - 728 - PTD 2000990 - Type Test SPT Test psi 1933 IA 95 2227 • ! 2217 2213 Interval) !P/F OA 5- — — 4YRTST P 270 525 515 512 Notes: Tuesday,July 14,2015 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate Il Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other aC/G/5/-2 n'I ✓ 2 Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5 Permit to Drill Number: 200-099 3. Address: P O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service IZ 6. API Number: . 50-029-21904-01-00 7. Property Designation(Lease Number): ADL 0028260 8. Well Name and Number: PBU M-29A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary: RECEIVED Total Depth: measured 10773 feet Plugs measured 10640 feet true vertical 9039 feet Junk measured 10650 feet J U L 0 6 2 015 Effective Depth: measured 10640 feet Packer measured 8573 feet / true vertical 8908 feet Packer true vertical 7731 feet /"'//��QG CC Casing. Length: Size: MD: TVD: Burst: Collapse: Structural Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10145-10170 feet 10245-10270 feet 10350-10375 feet 10696-10761 feet 8693-8695 feet 8715-8724 feet 8962-9027 feet True vertical depth: 8690-8690 feet See Attachment See Attachment See Attachment Tubing(size,grade,measured and true vertical depth) Packers and SSSV(type,measured and 5-1/2"TIW Packer 8573 7731 true vertical depth) 12.Stimulation or cement squeeze summary: 10145'-10375' t Intervals treated(measured): sf A'1.1�tipi�� ,1 I !L •1 0.1)15 Treatment descriptions including volumes used and final pressure: DAD Acid:30 BBLS 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14 Attachments'(required per 20 AAC 25 070 25 071,&25 283) 15.Well Class atter work: Daily Report of Well Operations ® Exploratory 0 Development 0 Service I3 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG Z GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt: 315-app Contact Summerhays,Nita M(WIPRO/ -chnologies) Email Nita.Summerhays@bp.com Printed Name Su merhays, •)A(WIP'0 Technologies) Title Petrotechnical Data Manager Signatu - /�-4 'j� -; Phone +1 907 564-4035 Date 07/02/201 VT', -7-//s/5 .t,,i - 7 2015 Form 10-404 Revised 5/2015 \ Submit Onginal Only 0 ¥ m C 3 9 \ O c __ i,= g O E m = G m@ c * 7 ? / /_ _ < R § / = i / m 3 / •� � �� - OgU \t % • \ k 0 / / k � 0 c 2 % ° 0 \ / ./ / w\ a � w ci) CC ee § = CO a3 't / \ \ E \ / / / sa /., \ to 0S ° % / 2 / \ \ 2 / 2 ® e 2 e - o n o ooa4- ± 2 C ® & ± = 'e f 2 = c = m O $ o O 6 a m \ [ [ \ \ i %) G ° 5 E / y co_ 2 0 7 7 E % 5 ® k 0 ■ % \ 0 o k 7 7 » § » /\ / / �� 2 c / i CO E CZ \ (D d - / \ % oc m § / $ / E e L. 2 ƒ w = o .\ •w y e m e o = a 0- 5 o o a - /.Rom co 2 E _ E U 7 '- E co -o =• ate \ \ \ / E eL/ / / / / ƒ \ / / S / ± g ¥ \ . co ƒ i »_ ° a 2 \ 2 % 2 0 C. S 7 .. E ® 0 c - % ± b c I ,_ = U = I % & o - ® c @ @ g co/ a G ± [ » . e 9 9 0 — -o c 9 = g 0 e a o c = / \ p \ / § .2 / \ w \ \ k 3 k® E .- _ \ k \ & - 0 a / = / / \ / $ § \ / / k / 2\ E D o 0 0)~ % \ /a : \ 2 / \ k\ 2 e & g e CO § •_ £ / e 0 � ! Z H co R = > -a - r e R © E ± I \ 0 O ƒ - ® / (CI)) / ƒ \ f ? O \ q ° C -J a 2 a $ .k.g o o g a = c ± = c 6 0 I » D O » D -) ® ®% 2 0 » 2 5 E O \ / Y w@ \ ƒ G 2 (13 [ ± 2 ± / \ I / % c• O O -I y_ 2 O CC co® D ® f 70 ® � f - CO - $ - CO \ \ 2 / , 0 / / w / ± f / ± f \ 2 0 § f / o / f 2 o n .k: ± U J 2 6 < « 2 U > t O m o c61 f U t U U < 2 4 .g t 2 2 ,- m o o $ I— Lt.' R \ r r r e \ / d / / © / $ \ \ / 7 \ CO & r e m & \ 5 © + ~ ¥ CO CO 6 0 « • m .00 0 0 0) 0 0 ia � COCDNco 0) _ CO N f— O V (N.1 LO U .50000 0 0 0 L. 0) N N- CO Ln "Zr 7 �t O a0 r- M N mN-- N- CO M V CO CO LO LU O N- CO N M CO O) N- H CA N- CD c- CO Ln CA CO V CO CO N CO N- N N- Q) M M M M LC) O) co co 00 CO d' Ln O Ln N- = N 0) O) CO CO i I I I I QC O) 0) M CNI — - co V CO CO C) ' M CO N N-N- (0 CV LO M cCC _ WM EL O co O CO O V = J J CO J 00 J d * 4$ J co J It .N N (0 CD 00 CO N _ N CN LO N— N O CV Ln t ++ N LO Ct N O C0 M V N Ln N C co CO 01 N O) N CO J W I � � 010 HU 0 W W 00u_ fXa a Z Z Z a W W W M m O D I— Z_ Z_ 0 0 Ou) Z = = F- H T VV8 ELLE 63/8'CNV .!Y NOTES:H2S READINGS AVERAGE 125 LHEAD= 141cEVOY M -2 9 A s, WHEN ON MI***WELL REQUIRES A SSSV ACRWTOR= BAAKER C ppm KB.ESV= 56.11' I I WHEN ON MI*** WELL ANGLE>70°@ 9744"" BF.(TEV= 28.11'' KOP= 3189'_ Max Angle= 103° ,991T [tum MD= 10581' I 2098' H7"OTIS SSSV LANDING MP D=5.962' Datum TVD= 8800'SS - C) L . 13-3/8"CSG,72#,L-80-BTRS,D=12.347" H 2693' —A 7'TBG,26#,L-80-NSCC, .0382 bpf,D=6.276" H 8498' , 8498' —{7"X 5-112"XO,D=4.892" Minimum ID = 2.387" @ 8654' I 8509' —J5-1/2"OTIS XA SLD SLV,D=4.562- 2-718" LINER XO Z 8573' H9-5/8"X 5-1/2"TNV HBBP FKR ' , 8631' —15-1/2"ORIS X M.D=4.562" TOP OF 2-7/8"LNR —{ 8648' 8648' 3.72"BKR DEPLOY SUB,D=3.00 J II , 8675' —15-1/2"OTIS XN NP,D=4.455" 5-1/2"TBG,17#,L-80-BTRS,.0232 bpf,ID=4.892" -1 8719' Ii 1 8725' —{7'TMV SEAL ASSY W/O SEALS TOP OF 7"LNR H 8720' 9-5/8'CSG,47#,L-80-BTRS,D=8.681' —1 9522' --• ' 7'IVLLOUT WINDOW(M-29A)9533'-9540' TOP OF 7"BAKER'Al I STOCK —{ 9530' / 2-7/8"LNR,6.16#,L-80, .0058 bpf,D=2.44" H 10696' ` ♦ti!•••• 0164./•♦ r LNR,29#,L-80,.0371 bpf,ID=6.184' — 10270' 0••+•1•.•.•.•. / 10640' HHES CEP(04/18/03) �•i$i$i••••• 44.4.4...4.... ? --{FISH-(3)1-1/16'ROLLERS PERFORATION SUIVIWkRY REF LOG:SRT:RY MWD/GR ON 07/16/00 ANGLE AT TOP PERF: 89°@ 10145' ,, ‘sihr Note:Refer to Roduction D8 for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2 6 10145-10170 0 04/18/03 2 6 10245-10270 0 04/18/03 2 6 10350-10375 0 04/18/03 2-7/8" 10696-10761 SLTD 07/21/00 2-7/8"LNR,6.16#,L80 STL, 10773' .0058 bpf,D=2.441' DATE REV BY COMMENTS DATE REV BY COMWE'1TS PRUDHOE BAY UNIT 02/04/89 NTIAL COMR.AS INJECTOR 01/18/12 TMN/JM)ADD®H25 SAFETY NOTE WELL: M-29A 07/18/00 JCM CTD SDETRACK 04/22/15 RB/PJC TREE C/O FERMT No:`2000990 01/15/01 SIS-MO NT1AL REDRAW 04/29/15 RJK/RIC RLL INERT API No: 50-029-21904-01 03/08/02 RIJ'TP CORRECTIONS SEC 1,T11 N,R12E,226T FSL&605'FEL 04/18/03 DDW/TLH ADD FEW&CSP 02/10/11 MB/JM) ADDEDSSSV SAF-EIY NOTE BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday,June 26, 2015 4:42 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Team Lead;AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; Peru, Cale;AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R;AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; Regg,James B (DOA) Subject: UNDER EVALUATION:Injector M-29A (PTD#2000990) Due For AOGCC Compliance MIT-IA Attachments: image002 jpg; image003 jpg; image001.png; image004.png All, Injector M-29A(PTD#2000990)was due for regulatory compliance on 03/07/2014.The well is now available to be brought online for compliance testing. This well is reclassified as Under Evaluation and placed on a 28 day clock. Please use caution when placing the well on injection as the annuli are fluid packed. Please call with any questions or concerns. Thank you, SCANNED ,JUL 0 12.015 Kevin Parks 4ltet nate l4 httne\ I 'ttus! BP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: ', :C Well Integrity Coordinator Sent: Thursday, ne 18, 2015 9:05 PM To: AK, OPS GC2 0 • K, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, .:C Well Services Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; RES GPB East Wells Opt Engr; Peru, Cale; AK, OPS Well Pad MN; 'ch ris.wa l lace@a laska.gov' Cc: AK, D&C Well Integrity Coordinator; A , !:C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; 'Regg, James B (DOA)'; Sternicki, Oliver R; Pettu , hitney; Weiss, Troy D; AK, OPS FF Well Ops Comp Rep Subject: NOT OPERABLE: Injector M-29A (PTD #20. ••0) Due For AOGCC Compliance MIT-IA All, Injector M-29A(PTD#2000990)was due for an AOGCC MIT-IA on March 7, • 4. The well was recently placed on injection to facilitate state testing but rates have yet to stabilize. Due to surface co raints,the well will no longer be 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, June 18, 2015 9:05 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Team Lead;AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; Peru, Cale;AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; Regg,James B (DOA); Sternicki, Oliver R; Pettus, Whitney;Weiss,Troy D;AK, OPS FF Well Ops Comp Rep Subject: NOT OPERABLE:Injector M-29A(PTD#2000990) Due For AOGCC Compliance MIT-IA Attachments: image002 jpg; image003 jpg; image001.png All, Injector M-29A(PTD#2000990)was due for an AOGCC MIT-IA on March 7,2014. The well was recently placed on injection to facilitate state testing but rates have yet to stabilize. Due to surface constraints,the well will no longer be available for injection. The well is reclassified as Not Operable until ready to be brought back online and has been added to the quarterly Not Operable Injector Report. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) SCANNED .I!IN 2 6 2o1 BP Alaska-Well Integrity Coordinator GWGow;Wells O•gal talon WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D& ' - ntegrity Coordinator Sent: Saturday, June 06, : 2:09 AM To: AK, OPS GC2 OSM; AK, OPS 'eld O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Servi - •aerations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB Eas -IIs Opt Engr; Peru, Cale; AK, OPS Well Pad MN; 'chris.wal lace@a laska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well -_rity Engineer; AK, D&C Projects Well Integrity Engineer; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: UNDER EVALUATION: Injector M-29A (PTD #2000990) Due F. OGCC Compliance MIT-IA All, 1 p6k - zea zO oilo Regg, James B (DOA) From: Regg, James B (DOA) '€t4 61(11/5 Sent: Wednesday, June 17, 2015 9:15 AM To: Grimaldi, Louis R (DOA) Subject: RE: Need your opinion I'd postpone these; none appear stable to me. In addition, the OA in M-29 has increased above 1000psi; while the sustained casing pressure limits (2000 IA and 1000 OA) do not apply to injectors, it is still cause for concern and should be addressed. I would not make a definitive call right now that the annuli pressures are thermal. Jim Regg Supervisor, Inspections AOGCC �015 333 W.7th Ave,Suite 100 S�pNNED JUL 4 2 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Grimaldi, Louis R (DOA) Sent: Wednesday, June 17, 2015 8:20 AM To: Regg, James B (DOA) Subject: Need your opinion Jim, Please take a look at these T/I/0 plots. M-30 looks good to me but 28 & 29 are still climbing on the IA pressure. I'm guessing from filling the IA and that fluid is heating up. Just wondering if we should be getting on them at this point. I am working in the office up here so you can call if you have time. Lou Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907-776-5402 (Home) 907-252-3409 (Cell) Lou.GrimaldiAlaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Lou Grimaldi at 907-252-3409 or Lou.Grimaldi@Alaska.c ov. 1 $so8§c 4vi t?, § . 0 a 0 c rn I v, it LL � I t� TREE= 6-3/8"aW A o '2 9 A GTUATORppm WHEN ON MI* GE 125 S NOTES:H2 __ _WELL REQAVUIRES A SSSV KB.H..EV= 56.11' 1 WHEN ON MI*** WELL ANGLE>70°(r0" 9744'*** BF. H_EV= 28.11' KOP= 3189' Max Angie= 103°@ 991T Datum MD= 10581' 2098' H7"OTIS SSSV LANDING NIP,ID=5.962" Datum TVD= 8800'SS 13-3/8"CSG,724,L-80-BTRS,D= 12.347" --1 2693' — 4111 r 7"TBG,26#,L-80-NSCC,.0382 bpf,ID=6.276" —I 8498' -. 8498' H7"X 5-1/2"XO,D=4.892' Minimum ID = 2.387" C17T 8654' I ' 8509' —I5-1/2"OTB XA SLD SLV,D=4,562" 2-7/8" LINER XO Z Z 8573' --I9-5/8"X 5-1/2"TM/FDBPFKR M , 8631' —I 5-1/2"OTIS X Nei',ID=4.562' TOP OF 2-7/8'LNR --I 8648' F.: 8648' —3.72"BKR DEPLOY SUB,D=3.00" ' , 8675' —I5-1/2"OTE XN FAP,D=4.455" 5-1/2"TBG,17#,L-80-BTRS,.0232 bpf,ID=4.892" * 8719' r 1 8725' —17"WV SEAL ASSY W/O SEALS TOP OF 7"LNR — 8720' j 9-5/8'CSG,474,L-80-BTRS,ID=8.681" H 9522' -, ` 7"MLLOUT WINDOW(M-29A)9533'-9540' TOP OF 7"BAKER WHIPSTOCK —I 9530' ,/// 5 2-7/8"LW,6.16#,L-80,_0058 bpf,D=2.44" --I 10696' '-;1 s, ` x S. *6..00 ••••••♦ 7"LW,29#,L-80,.0371 bpf,ID=6.184" — 10270' •••••••410640` HFBS GBP(0411$!03) .••••••,,.1...1 •''•,.f{ / 444441.� ? —I FISH-(3)1-1/16"ROLLERS PERFORATION SAWARY REF LOG:SPERRY MMVD'GR ON 07/16/00 ANGLE AT TOP PERF: 89°@ 10145' , Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2 6 10145-10170 0 04/18/03 2 6 10245- 10270 0 04/18/03 2 6 10350-10375 0 04/18/03 2-7/8" 10696-10761 SLID 07/21/00 2-7/8"LNR,6.164,L80 STL, 10773' .0058 bpf,D=2.441" DATE REV BY COMvENTS DATE REV BY OONMENTS PRUDHOE BAY UNIT 02/04/89 NTIAL COWL AS INJECTOR 01/18/12 TMN/JMD ADDED H2S SAFE(Y NOTE WELL: M-29A 07/18/00 JCM CID SIDETRACK 04/22/15 RB/PJC I I IL C/O PERMT No:`2000990 01/15/01 SIS-MO FERAL REERAW 04/29/15 RJK/PJC PILL FISERT AR No: 50-029-21904-01 03/08/02 RN/TP CORRECTIONS SEC 1,T11N,R12E,2267'FSL 8 605'FEL 04/18/03 DDVVM_H AIX)PERF&CEP 02/10/11 M3/JMf ADDED SSSV SAFETY NOTE BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, June 06, 2015 2:09 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale;AK, OPS Well Pad MN;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA) Subject: UNDER EVALUATION:Injector M-29A (PTD #2000990) Due For AOGCC Compliance MIT-IA Attachments: image002jpg; image003.jpg All, Injector M-29A(PTD#2000990) was due for regulatory compliance on 03/07/2014.The well is now available to be brought online for compliance testing. This well is reclassified as Under Evaluation and placed on a 28 day clock. Please use caution when placing the well on injection as the annuli are fluid packed. Please call with any questions or concerns. Thank you, Kevin Parks (Alternate Whitney Petty W �� BP Alaska-W5 ell Inte rity Coordinator 5�. +A� ( U JUN 3 Global Wells Oryanizatior Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From'AK,D&C Well Integrity Coordinator Sent: Friday, February 21, 2014 7:02 PM To: AK, OPS GC2 SM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES ast Wells Opt Engr; Peru, Cale; AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; 'jim.regg@alaska.gov' Subject: NOT OPERABLE: Injector M-29A (PTD #2000990) Due For AOGCC Compliance MIT-IA All, Injector M-29A(PTD#2000990) is due for an AOGCC MITIA on 03/07/2014. The well will not be ptackd on injection prior to the due date of the test. The well is reclassified as Not Operable until the well is ready to be placed-on injection and tested, and will be added to the Quarterly Not Operable Injector Report. 1 v OF T4 aw\� 1/j, s THE STATE Alaska Oil and Gas • 4V 'i��i� ofA L A S KA Conservation Commission *et2__= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907.279 1433 OF ALAS"' Fax 907 276 7542 .1O (} 1 2.015 www.aogcc.alaska goy Cale Peru Production Engineer 0°— D 1 BP Exploration(Alaska), Inc. O� P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool,PBU M-29A Sundry Number: 315-300 Dear Mr. Peru: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision,or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this ' day of May, 2015 Encl. • \„` RECEIVED • MAY 14 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION �� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown❑ Suspend❑ Perforate❑ Other Stimulate 0 • Alter Casing ❑ Change Approved Program 0 Plug for Redrill❑ Perforate New Pool CIRepair Well ❑ Re-enter Susp Well ❑ Other: /fGl/5 QLD 2.Operator Name: 4.Current Well Class. 5.Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 200-099-0 • 3.Address: Stratigraphic ❑ Service 0 • 6.API Number: P.O Box 196612,Anchorage,AK 99519-6612 50-029-21904-01-00 • 7.If perforating. 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU M-29A ' Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s). ADL0028260 ' PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft). Effective Depth MD(ft). Effective Depth ND(ft). Plugs(measured): Junk(measured). 10773 • 9039 • 10640 8908 10640 10650 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20”91.5#H-40 31-111 31-110.99 Surface 2662 13-3/8"68#L-80 30.5-2692.76 30.5-2687.17 5020 2260 Intermediate 9435 9-5/8"47#L-80 28-9462 92 28-8511.37 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 5-1/2"TIW Packer Packers and SSSV MD(ft)and ND(ft)• 8572.74,7730.84 No SSSV Installed No SSSV Installed 12.Attachments. Descnption Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations. OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16 Verbal Approval: Date: GAS ❑ WAG 0 • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Cale Peru Email Cale.Peru@BP.Com Printed Name Cale Peru Title Production Engineer Signature 47, Phone 564 1522 Date 0 a1 i`�r/7 015 Prepared by Garry Catron 564-4424 COMMISSION USE ONLY 'Y' Conditions of approval: Notify Commission so that a representative may witness Sundry Number 315 - 300 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ I Other. Spacing Exception Required? Yes ❑ No l Subsequent Form Required: /C-404- I L4 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date. .S."-•••26 _4( v'-` 67` J`s ORIGINAL �C\ MAY 2015 RBDMS � ;.I-5-; ;fForm 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments'n Duplicatg, o 0 0 co 0 co co 03vaocococococo 0 = J J J J J J a) Q o O 09 0 0 0 Co N CO — a: N ) N N p V I- N Ln U ) o o ,2 0 0 0 0 O CO N V V CO - N- O N N- CO <- CO CO L0 I- N- a) Cn C3 r a) V I— co CO CO I- CO rt CO Ln O LC) CO CO CO 0) CO N I— N- Q O • CO N I- CO CO N r-- > N- C` r-- L._L (13 p - E EN a) co co c7 c7 c7 La OD m co c') 0) co (NJ O Q 0)) C7) N CO CO � Q 'J Q (' Q op v °' co coo U Q C, CN CO I- cr) N LC) co co co O O co• • co - f, J O J O 00 = J 4$ 09 co J N CO J colt J *k N Ct) *k CO *k O - CD (O N 00 N CV N• a) N LC) • L L() N IC) N ZT O M N N CO Ln C co Vr c CO LC) J CA N N co Q CT� W LU U 0 Z Z Z W W W CO m Q H Z Z D J D U Z -1 -J (nF- F- Perforation Attachment ADL0028260 Well Date Perf Code MD Top MD Base TVD Top TVD Base M-29A 4/18/03 PER 10145 10170 8690 - 8690 M-29A - 4/17/03 - PER 10245 10270 8693 8695 M-29A 4/16/03 PER 10350 10375 8715 8724 M-29A 4/16/03 BPS - 10696 10761 8962 - 9027 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: M-29A Well Type: WAG Injection Well API Number: 50-029-21904-01 Well Activity Conventional 4 Classification: Activity Description: Acid/SBG Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, 50 bopd: Job Type: Stimulation Estimated Cost, $240 $K: AWGRS Job Scope: ACID Other regulatory none requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Yes Primary Secondary Required? Engineer: Cale Peru Contact numbers: (907) 564-4522 (832)316-5774 Well Intervention Engineer: Michael Hibbert Contact numbers: (907) 564-4351 (907)903-5990 Lead Engineer: Dan Robertson Contact numbers: (907) 564-5546 (907) 529-5818 Date Created: May 4, 2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) (psi) Cut (%) (Mscf/Day) 7/15/2011 - 3,700 - - - - 460 Current Status: Not Operable Shut In Inclination >70°at Depth (ft) 76°@ 9,779' MD Recent H2S (date,ppm) NA Maximum Deviation (Angle and 9,917' MD - Depth) Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 52° 9,814' MD Reservoir pressure(date, psig) analog 3,250 psi Minimum ID and Depth 2.37"@ 8,648'Top of 2-7/8" LTP Reservoir Temp,F 220° F Shut-in Wellhead Pressure 1,200 psi Known mech. integrity 7"tbg in poor condition, up to 66% pen. The well is non operable because its MIT-IA due date lapsed due problems(specifics) to a flowline replacement. Flowline is repaired now. Last downhole operation (date, operation) 4/28/2015 SL-B&F, caliper. RAN 10' x 3-1/2" PUMP BAILER TO 8,648' MD Most recent TD tag(date,depth, 4/28/2015 9,628' MD toolstring OD) RAN 2.25" PUMP BAILER TO 9,628' SLM, DEVIATE OUT. RAN 5.5" BRUSH &4.51"GUAGE RING TO 8,560' SLM. Surface Kit Fit-for-Service? YES If No,Why? Flowline recently trippled. Comments,well history, Call WIC before starting job.Well was SI for flowline issues which are repaired now but it lapsed on background information, its MIT-IA requirement. Need to bring on under eval at the end of this job to do the iProf. etc: M-29A recently had a tree CO. During that job a B&F and caliper were performed. After one tbg volume had been pumped while brushing, injectivity went from —1.2 bpm at 1000 psi tbg pressure down to—0.3 bpm at 1500 psi, indicating the perfs had been plugged. A caliper was then run,7"tbg is in poor condition, explained above.Then a freeze protect had to be slowly pumped essentially using the lube and bleed method. The purpose of this coil job is to re-establish injectivity(-3.5 bpm at a WHIP less than 800 psi)by; RIH tag fill. Spot acid across perfs. Inj test. Fluff and stuff. Inj test.Jet SBG while running to surface. lnj test. Spot acid across perfs. Inj test. PO1. iProf/warm backs. Other notes: M-29 was originally completed in 1989 and CST'd in 2000 through original tbg. In 2010 it passed an MIT-IA to 4000 psi with 1000 psi on the tbg. In April 2015 the well had 1700 psi on the tbg with no pressure on the IA.These things are noted to support the attached burst/collapse modelling. There are comments in DWF about adding perfs near the heel.The Hall plot indicates the CIBP and/or the Bonzi cement is not holding (CBL run during completion indicates the cement is good). I don't think adding perfs would change conformance at the moment and would like to review the iProf data and warm backs before adding perfs (have not had an iProf to date). Well Intervention Details Suspected Well Problem: Perfs plugged with schmoo and or brushed scale. 7"tbg also in poor condition. Specific Intervention or Well Objectives: 1 Re-establish injectivity,3.5 bpm at a WHIP less than 800 psi. 2 Key risks,critical issues: Mitigation plan: Review caliper and modeling results. Ensure IA is liquid 1 Burst or collapse corroded 7"tbg. packed.If it is necessary to have more than 2000 psi on the tbg hold 1000 psi on the IA. 1 Locking up with freezable fluids in the well after coil Plan to put well on PW and run iProf with coil. Should leaves. have confidence the well won't lock up before leaving. Summary Step# Service Line Activity 1 D Echometer shot;tbg and IA. If IA fluid level is more than 500'from surface, fill it up with diesel. Coil may need to apply pressure to the IA during job. 2 S Drift and tag at WSL discretion. Each interval of pipe was drifted 4/28/2015. 3 C RIH tag fill. Spot acid across perfs. lnj test. Fluff and stuff. Inj test. Jet SBG while running to surface. lnj test. Spot acid across perfs. lnj test. POI. iProf/warm backs. Detailed work scope (If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 D Echometer shot;tbg and IA. RIH tag fill with 2.28"JSN. Not planning to pump on the way down to minimize returns at surface,the well has little or no injectivity. At tag depth; pump freeze protect out of reel then a 20 bbl spacer of 1% KCL, likely have to take returns at surface. Spot 15 bbl of Dad acid. Recipe: 80% HCL(7.5%)to 20% Xylene, standard additives.While making 2 C passes across perfs (10,145 to 10,375'). Let soak 30 mins. Over flush acid with 200 bbl of 1% KCL(into perfs) down backside while doing post acid injectivity test, don't exceed 2000 psi without putting pressure on the IA, see key risk critical issue section. Ideally establish a stable injection rate at 1000 psi CTxTBG backside pressure. Contingent fluff and stuff. Desired clean out depth is to the CIBP, minimum is to 10,500'to make room for warm back passes later. Pick up motor and mill if necessary(call APE if jetting becomes difficult after 10,500' to discuss if picking up motor and mill is necessary, probably not). 3 C Jet with SBG, small bites, chase fill above perfs to ensure debris goes into formation. If it is necessary to exceed 2000 psi put 1000 psi on IA first due to tbg condition do not exceed 3000 psi tbg pressure. Do post fluff and stuff injectivity test(establish stable rate at 1000 psi CTxTBG backside pressure). Jet SBG while running to surface.Assume 60 fpm at 1.5 bpm. —270 bbl total of SBG. Post SBG injectivity test. 4 C Run back in hole. When at top of perfs pump 50 bbl 196 KCL spacer. Spot 15 bbl of Dad acid. Recipe: 80% HCL[7.5%] to 20% Xyelene, standard additives.While making 5 C passes across perfs (10,145 to 10,375'). Let soak 30 mins. Over flush acid with 200 bbl of 1% KCL(into perfs)down backside while doing post acid injectivity test, don't exceed 2000 psi without putting pressure on the IA,see key risk critical issue section. Put well on produced water(under eval). 5000 bwpd,WHIP should stabilize at less than 700 psi if job was 6 Ops successful. STP iProf and warm backs,see template. Ideally we would have the well on for a longer period of time before doing the iProf but we should be able 7 C to see if the water is rushing below the CIBP or behind the liner.This will also give the well some time on PW with coil there in case it locks up again. Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: NA MMSCFD: NA BWPD: 5000 Expected Production Rates: FTP(psi): 700 Choke setting: NA Post job POP instructions: POI under eval. 5000 bwpd, 1100 psi max well head pressure. Perform State witnessed MIT-IA. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: TREE* 7.1ne Cat. SAFETY NOTES:1425 READINGS AVERAEL 125 WELLAFAO• McEVOY ACTWTOR* O M-2 9A ppm WHEN ON MI.WELL REQUIRES A SSSV Kr)FLEV• —_- 5611 WHEN ON MI SI TO_NR 10696'-10761' WELL 37 MEV• 2611 ANGLE,70'Af 9744'. KOP= 31- Vas Anne• 103'e981 Ovum AD= 10581 Q 2096•--±7'ons SSSY t.A 07G NP 0=5 962' CM"IVO• 860D• - 1134"C30,721 L•60 8TRS,C•12 347• �--- Minimum IO=2.3r g 8648' TOP OF 2.716"LINER fr Tso 291 L-80-t4tcc,03s2 opti0.--..27.--1-f $188• ] \ / - 6446 r x s'?70 tTOPOc s-1?'Teo __8446• f----- •�7! {! 1—L!1_._39 s,? 0Ti5>A SLEMYG SLY.0.4 562' S - 0 0.546'x5-1/rnWf58P PRA 1 81-157-11T s1a 015 NP,0.4 562 'TOP OF2.7/6'LAR H 64.73 LI, 6646' OEPLOYNEATSUB I 6876 6-,rr ons>N rev.0.4 4515' I }(1 -- rI7•TIN SEAL ASSY WoSEA SI Cs-11r 7/13 171.L-01.6TR5.can 4p/ 0=4 e9r� 6� (TOPOF r LHR H-----6;7201 , 1 19-5er -{- 8720' : 9.519'C50,4711,L•0.6T13S,D•6691' 1--1-16-ii 7'*AL LOUT WNOOW 9633'•9610 TOP OF r 6A KER WNPSTOCK -{ 9690' 1.2,7A9*oak6 16f.L 60 0056 Opt.0•2 44' ^{ 10646' 10610' MES C ("AIM)I f wet..1-les 3L4/LNR 1-1 16610' , ••111/111111/1111 • 11111/1/ ,', P610 - 10266' 1.1,1,1,1, 1.1. • 4.1/4'1.11.4 • 411111*111+1111• �TOPOf 2'airLNR ..L....1 [7'LTR,296,L-10 0171 opt,0.6 164' 10270' .11444.1. 1 PERFORATION SlhWRI FISH•(331.1Her ROLLERS HEE'LOG SFEi12Y1/A/12)1ONOm6A00 NWELLLOCA70KuNKN wn ANGLE ATTOP cE Dr 010145' 2.718 St.It)LNR6166 -1 10761' I Note Nota to Roouctwn PIS tot hstOrCai pM data L-60. 0056 opt ID.244' SIZE I SPF IYTERVA_ O40fS47 DATE 2 0 101@-10'70 0 04116670 2 6 10245-10070 0 0010103 2 6 '�•t0�0350.103750 0411'03 AO 2.7b' 2-716'LNR 618A,L60•STL,0056 opr.10=13T 10715' 761li1 SLID 07Q' DATE REV BY COW/WS DATE REV BY COk1V N S PRLAMOE BAY LINT (2704169 INITIAL MM?AS 611ECTOR #01r8112 TANIAID ACOED1-OS SAFETY NOT; WR 1 /A26A 0711800 JON CTO SCE-TRACK REBUT No"2000980 011So1 STS-M3 NRML 2£LWAW AR Na W-.729-21904.01 03/0602 RN/TP CORRECTIONS SEC• T•1K R12i,2267 c5L 6 1305 TEL 0171803 OOVWTL N ACD PELF 6 O8P 07110111 AQIJh0 ACCEOSSSV SAFETY NOTE BP Exploration(Alaska) Injection PROFILE V�0 1,02,5 Well: M-29A Prop.Code: CC or AFE:APBINJEC API#: 50-029-21904-01 Name:Cale Peru Contact numbers: (907)564-4522 Proc.Dist. Date: 5/4/2015 Contact numbers: (832)316-5774 Town: Contact numbers: APE Well File Objectives(In order of importance): 'Slope: IW/L(3) FE Looainq Notes: 1)RIH with: GR/CCL/STP It Gradiomanometer is needed,give inclination of logging interval NO 2)Other Into: PPROF Logging Summary—Tie-In Log: Pass Direction Speed(fpm) Depth(ft,md) Notes iPROF Dynamic Up/Down 30 CIBP'(10,640')to 10,000' Dynamic Up/Down 60 CIBP'to 10,000' Going to 8550'to see if water is exiting behind liner.If it is difficult Dynamic Up/Down 90 CIBP to 8,550' getting in and out of liner lust go to 8550'on the last up pass.Don't have to go back and forth. Stops Stops 8600 5 mins 8750 10000 CIBP Warm Backs Warm Backs 1,3,5 hr warm back passes 10,000'to CIBP MCNL/Borax Logging Summary-Tie-In Log:'';* F i"//r, 2%W, f/ Pass" } Direction 'Speed'(frond Depth(ft.,r ,%0,V 1, //42,,�4 r /_fes, IPROF/MCNL LOG PRESENTATIONS 1.Job Comments—operating steps in sequence,Flow rates for logging passes and basic field interpretation including production and injection splits. 2.Flowing Overlay—Spinner,temperature and pressure data from the 60 fpm up passes. Presented on a 5'7100ft Note flow rates for flowing pass in log header. 3.Flowing UP Pass Overlay—Spinner,temperature and pressure for 40 fpm,60 fpm,and 80 fpm passes. 4.Flowing UP/Down Pass Overlay—Spinner,temperature and pressure for 60 fpm passes. 5.Production/Injection Overlay—Spinner,temperature and pressure for 60 fpm up passes. 6.Baseline Injection/Borax Overlay 7.GHOST Log Schium u PDC AND TEMPERATURE MEMORY GR/CCL/TEMP 15 APRIL 2003 FIELD Company BP Exploration (Alaska), Inc. W n Well 11-29A WJ Z- o Field Prudhoe Bay '. Borough North Slope State Alaska 0,-: Location: SEC OI, TWP 11N, ROE 12E Other Services u u m Surface: 2267 FSL & 605 FEL 5 iii en API Number: 50-029 21904-01 Permanent Datum HSL Elevat ion 0 Eley: KB_ 56 Log Heasured from RKB 56 Ft. Above Datum ELF. 0 Drilling Meas. from RKB 6..L.. 0 — Date 15 APR2003 IL Shot No. of Pert Interval Run No One Density Shots From To Type Log rEtnORY 6R/CCL/TEMP Forst Reading 10757 FT Last Reading 9590 FT Max Dogleg + ,Six Dermal ion 103 0E6 to 99T7 FT Oept Reached IO759 FT Bottum Driller 10773 FT Well Head Pressure 0 Gun Type: Fluid Level Surface and Size. 4 Truck No 2113 CASING RECORD a Size-MtChes Weight-lb/ft From To Recorded Ely BRANDON PELTIER 9.625 IN 47 LB/FT / SURFACE 8771 FT Wrtnessd Bum _ DOUG 111O11f6011ERY _ 701 26 LB/FI 8260 FT 9295 FT COLLAR LOCATION WNW SERVICES Casing Tubing Service Type Size Depth 1 Bottom: Seat Nipple. Tubing ,junk Basket Size: Gwge Ring Number UP AND DOWN PASS OS 7EMPEPAT WY OV RLAY f 2603-04-16 l i S t I i45 ___ _ _ Y[EP-IPI C','" DCCT 90 OO 145 00 14114-41P214114-41P2 'E5 ww wn_._ww r . w �.. c.rr< r rv...nr.1...nu+ R Pass NO 0 Ali PASSES L066E0 AT 60 FM Loggia W ills'TEPPOR SHUT IN 6 PGG*IN 0 ALL GASSES L066E0 AT 60 FPR LG99,0 W Flip'UMW SNUf 01 ;- - -_ 96001 1 i - r 1 r ________________Mill=a - _ I I T r; 1 ' 1 0111011 - 9650 - _ rli MIN NM _itl I 1 [ 1 -MIN 1 1 i i iiiiiiii IMP1 9700 L.,_ I I ii I C"'"--404, I 9750 - - 4 i 7 1 ' t. . _ _ .j_ ..,_ _ t- i I t i — simmimminis=me 1111111111111=W1111.1 --___-_----al rIII-- S 9800 ------IM--I---_wa�1iQ . 1:i 1 1 1 1 ) 1 .111'1__1 I I 111 1 1 1 1. 11 _I I ttf I \ \ \ \ \ \ \ I F f — --_ 1 1 r-- F . 9900 -.. I1 I _ ; t 1 4 9950 1111■ _ t ' 110 I --•• , -; ' Ifill , „ ' a --_ s :s ' �; ....., _ , II -, .......1 >- 1364 1 , is Pt:L ref, • ._..+ T wow4 ............_ 1�s=a11ssium � ; 1:�== --`NN 1.•1—N• NN- - N••NNSN.—NiiNiii =i ==MEL -1i—=====:Err. = NN—•• —N� � �MOM ii�•ii••IN�• •� � amamaiew M � s—NN••�--N N�= �NNi" � ;� a i tillnai:a✓::�_ -----------2•---:= inl[mii ea last 10100 i �illiils=si�=llllle sl= t - ----------anammumumnammAllo NN••—N . N---NN.7��NN�lINi—N—NNN Ni`N c t 1•111••••i••01MNINI.si••• •��_ ♦ N�—N N-n—NNNNNN 3 •r N NN-------NN••t— N----N !• 1•110•••—N!1•NNN—NN••--NN—NNS• NN.>♦NN i—N• ••--N-N_N-- �i ••NNNi.. —N N••--N—NNNN so MIN N—tom a/ —N N•• NNr —NNNN_• •••••••••••••••••••••1111111••• MINNMIPM NNM71—NNN—i IN -NNN NNNNN a N—NNN--N—N N NNNN N—--N NN_Nt• N111111111•1•1101•111111.11111•1111•••••••••••••••• =N,�NNNNN•••Ia t--NDN NNNNNN !911•------N • NNNNN NNNNNMI N 1•11••NNNNNNN. N—LI MIME N • so ••f�.>i—NNi.IN•1•• 10150 NN 717—i111111111—N—N Nil a• NNN NN N •••'-----N N-1/41 ■ TNN N--N N—IM• • MN NNNNNNNNNi NN—N —N------- --NNIA • —N------N liSiilsllii =••=ll•lsll ilsiiiliil 111111111•••••.. • I—NN----- INIIIMININIMMP� ■�SGe IIIIIIII IIIII �••Li —N--k � MIN NN---NNNN N--NN MS 111111i11E , 11111111111•11.111111111111111111111111111111111111111 IMMUNE! —NC INININIMINNIM=NI1111•1•••••••••••••••111111111111111111111•••••�N_N---l— 11111111111r 4 10200 li�lllll �M111iilf1111il ---•.. I N ---N'01111' liilllllllsii'iiiss�l __ i!-- !!Bill=ileiMINIMINNINNEMMEN IMMUNE 1111111111=111 _• IIIIIIIMMV !li�MiillliilC�=ice=ii�� ■111!11!!=iiiIIIMMINIIIIIIIMI11111111111•1111.114 yNINNNI • ■i1.1s11llRIM=111111lliiii111l M_N----• NNNNNNN--MI a __ NIS---NN—a — N—MMf♦� luiir t, _ lin SWIM..NM..MINIIMINIP INM=110 10250 —N.� ••---R N. Ia Aa1IMM111111111111111111111111 11111 1111 '1111111 ==:, ===== liiiiiiaiss UMsl =� ■irjliilalr" N•1M•N ----: !iii =1111 1.11131 i1sS�—aIII.L 1111111111I u'1. == .'�..N': s"Zr..'=: ----- hill ■------, N—Cr---.r--s ------'a"---- [11!w11 1 -mss �:C�M=: Si=__Ssiis. [i ssIMMO zm ! NNNN• NMMiW NN—NN----••-7!— __—s•IN.••••1_--NaI D 10300 ��—N•�—•�N N•rN7.N N_' Msl•e= NIIiIV nn II m S--N---! 1— M •-7. 1••ltiu N—•IM N— MN—•m—amity SaNM _• rNN---; 2N• NN• iii. niii 1 iM1 N•1 -i • • . N—.�•N.N NNN—N1�•� k i E N s i k 1521 A 18q - 2 o 1-21 Sorg A1-0- 1 X LL ! ii ° m q n o F-1 c 3 a E n m u n _,,.$� 41� 8 g p 3 m VI" E m m � ��f?R ie �aA�� zr o n a..... �i "I'''91111111111 8 Of j o 888 88888888 :', 2 rn W S �ntn H00§§mm 11111111111111111 F.? 888 MIIIII IIIIIIMIWNIII N N g .,,L,.!,4N ,”---4, �,�,RM,7 lC NNNNNNNNRRR�&RT I F 8 4�� 88888888 IIIIMIIMIRM E r 2',;. a A m m e a v u 3 t k $u N NNnRRRRRRK, NNNNNNN mommmmmnn y 2 8 S V X3 E 4 c a It g ' 781 F E amms11ss sssN sss1ss NNNNNNNNN e o 2 a va € ;8g *I- -o Doo neveeoif o 000000nnnno g is h I >' Ip %Li 11111112 11111111mmli; 3, u° y N NNNNNNNNNNNNNNNNN .g m E C 28 ocg S bS 2222222°82888222o 3aN A.8 1�til- 8 LLa ono l0000aao 000 opo oa0000 gg811 95 V U 8 8 O O O oy� ��JJo m $ a' $ A m$I og000l N7gR�88mNRi^, R3 cia �`g m_O� $ 11 W N W omm,t Q 5 25 g s : ;i fr3m E' i3 '33n g Y dp a • • DATA ENTRY AREA:MUST ENTER DEPTHS,FLUID DENSITIES AND SURFACE TBG COLLAPSE REFERENCE DATA User Input Tbg Size Class Pressure Derated Depth of Fluid Tubing Conditions IA Conditions Interface Etc. Fluid Fluid 2 7/8'\6.5# L or N-80 11165 (Needs Entry) Density Pressure Density Pressure 80%. 8932 Depth-(TVD Ft) (#/gal) (Psi) (#/gal) (Pd) 31/2'\9.39 L or N-80 10533 7730 Enter Tbg= 0 Enter IA= 0 80%. 8426 8.5 34 2 8.6 3452 41/2'\12.64 L or N-80 7500 0 80%= 6000 0 5 1/2'\174 Lor N-80 6280 s 0 80%= 5024 s 0 T\26# Lor N-80 1840 1840 s 0 80%= 1472 0 s 0 FLUID GRADIENT REFERENCE DATA s 0 TYPE DENSITY GRADIENT 0 (#/GAL) (PSI/FT) s 0 15°CRUDE 8.05 0.4182 DATA ENTRY AREA:ENTER FLUID INTERFACE DEPTHS AND FLUID 0 28'CRUDE 7.40 03841 DENSITIES FOR ALL INTERFACES.ENTER SURFACE PRESSURES. 0 30'CRUDE 7.31 0.3793 DENSITIES REFER TO FLUID AT THAT POINT AND ABOVE.ENTRY 0 40"CRUDE 6.88 0.3572 POINTS ARE DESIGNATED BY RED LETTERING. 0 DIESEL 6.80 0.3531 0 100%METH 6.64 0.3446 0 50/50 M/W 7.49 0.3888 60/40 M/W 7.32 0.3800 Most recent TD lag I Pkr=3412 Pkr=3452 FRESH WATER 8.34 0.4329 Max Differential at Packer= 40 SEA WATER 8.56 0.4443 PROD WATER 8.51 0.4417 Brine Waler 9.60 0.4985 Brine Waler 10.00 0.5193 Differential Pressure across Tbg Bone Water 10.60 0.5505 Prod Gas @ 2000 1.14 0.0592 Prod Gas @ 1000 0.49 0.0254 Your Choice= 2 0.1039 Calc Differential Pressure I li EXAMPLE CASE -- Top of Well Calculated Threshold Diesel 0 2000 4000 6000 8000 10000 0 I I I ; I 9 IA Fluid Interface @ 2000'TVD. 1000 - I : 1 I I II 2000 - I I • II I I •/' 3000 - I ' ! 1 • 1 � Bene 10.6#/gal 4000 - I ' I I I II a I ( I I . ; 5000 - •I II 6000 I I I I 1 7000 - I I I Tbg Fluid Interface @ 8000'TVD I * ., ,,, II ,,., II 8000 . I I I'V' l 4' I I . -om Pressure 9000 - --71260 Packer Depth @ 8200'TVD. '/: IIII_ --51T171 Crude -•4 12512.61 10000 - -- - 31259.3# 27/8'/6.5# In~ Project Well History File Cov~[~age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They. are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. We,, RESCAN IGI OVERSIZED (Scannable) [] Color items: ,~ DIske~es, No. ~ [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: BEVERLY ROBIN VINCENT SHERYL~)/VINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL,~WINDY Scanning Preparation / x 30 = °~.~ 0 BEVERLY ROBIN VINCENT SHERY[(~INDY Production Scanning Stage I PAGE COUNT FROM SCAN.ED F.E: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: /¢~ YES NO ..,: ,,v,..., Stage 2 IF NO IN STAGE 1, PAGEIS) DISCRE~P~kI~CIES WErE FOUND: ... YES NO BY: BEVERLY ROBIN VINCENT SHERYL MAI~ WINDY J RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /S/ I Quality Checked (der, e) 12110/02Rev3NOTScanned.wpd • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg SP AWNED AUG 2, LUIL Alaska Oil and Gas Conservation Commission ©9/ 333 West 7 Avenue ),,00 Anchorage, Alaska 99501 aCif Subject: Corrosion Inhibitor Treatments of GPB M -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad M that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • I BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) M -pad Date: 04/14/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal M -01 1690780 50029200420000 Sealed NA NA NA NA NA M -03A 2011470 50029201020100 0.25 NA 0.25 NA 0.85 6/3/2009 M -04 1710230 50029201050000 0 NA 0 NA NA 4/14/2012 M -05A 1970810 50029201940100 0.5 NA 0.5 NA 2.6 6/3/2009 M -06A 1930930 50029203670100 0.25 NA 0.25 NA 0.85 6/3/2009 M -07 1790370 50029203730000 0.25 NA 0.25 NA 0.85 6/3/2009 M -08 1800860 50029204990000 1.75 NA 1.75 NA 10.2 6/24/2009 M -09B 2022200 50029205630200 6.25 NA 6.25 NA 44.2 6/3/2009 M -10 1810290 50029205670000 0.25 NA 0.25 NA 2.6 6/4/2009 M -11 1810570 50029205890000 0.25 NA 0.25 NA 1.7 6/4/2009 M -12A 2001510 50029205930100 0.25 NA 0.25 NA 1.7 6/4/2009 M -13A 2011650 50029205220100 2.75 NA 2.75 NA 17 6/4/2009 M -14 1801090 50029205120000 1 NA 1 NA 5.1 6/4/2009 M -15 1810850 50029206120000 6.75 NA 6.75 NA 55.3 6/4/2009 M -16 1810860 50029206130000 0.25 NA 0.25 NA 1.7 6/4/2009 M -17A 2000320 50029206280100 0.5 NA 0.5 NA 2.6 6/3/2009 M -18B 1930540 50029208550200 10 NA 10 NA 73.1 6/24/2009 M -19B 2081980 50029208970200 Sealed NA NA NA NA 4/13/2012 M -20A 1971990 50029209120100 8 NA 8 NA 52.7 6/24/2009 M -21A 1930750 50029209230100 0.5 NA 0.5 NA 3.4 6/24/2009 M -22 1830540 50029209360000 16 NA 16 NA 117.3 6/23/2009 M -23 1830550 50029209370000 0.25 NA 0.25 NA 1.7 6/4/2009 M -24A 2011260 50029209390100 0.25 NA 0.25 NA 0.85 6/24/2009 M -25 1860650 50029215700000 8 NA 8 NA 55.3 6/3/2009 M -26A 1920280 50029220040100 2.75 NA 2.75 NA 18.7 6/3/2009 M -27A 1930860 50029219920100 0.25 NA 0.25 NA 2.6 6/24/2009 M -28 1860740 50029215780000 1 NA 1 NA 4.3 6/3/2009 --- M -2�9A 2000990 50029219040100 1 NA 1 NA 4.3 6/3/2009 M -30 1920300 50029222550000 0.5 NA 0.5 NA 3.4 6/3/2009 M -31 1920320 50029222560000 0.5 NA 0.5 NA 3.4 6/4/2009 M -32 1920330 50029222570000 0.25 NA 0.25 NA 0.85 6/4/2009 M -33 1941160 50029225040000 20 NA 20 NA 133.45 6/24/2009 M -34 1941330 50029225140000 6.25 NA 6.25 NA 25.5 6/3/2009 M -38A 2011320 50029225190100 21.3 NA 21.3 NA 210.8 11/26/2009 • ! STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. ~ ~ ~~~~ I ~ FIELD /UNIT /PAD: Prudhoe Bay /PBU / M pad DATE: 03/07/10 OPERATOR REP: Torin Roschinger AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well M-29A ~ Type Inj. W TVD ~ 7,731' Tubin 950 950 950 950 Interval 4 P.T.D. 2000990 Type test P Test psi 1932.75 Casin 100 X4,000 4,000 /4,020 P/F P Notes: 4000 psi MITIA pre-MI service OA 150 620 620 620 Pumped 3.5 bbls to attain test pressure Declined to witness by Chuck Scheve Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In~. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) i l ~. ~J~1r1~J~°'' 1 MIT Report Form BFL 11/27/07 MIT PBU M-29 03-07-10.x1s Re: GNI-03 (PTD# 1971890), and M-29A (PTD# 2000990) MIT Forms . Thanks, Don. MIT report for M-29A has wrong well name (M-19A). No need to resend the report - I corrected our copy. I looked over the MIT done prior to swapping well to MI, and the 90-day TIO plot; we can accept the MIT as satisfying the 4-year requirement. Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Jim, Tom & Bob, Please see the attached MIT forms for GNI-03 (PTD# 1971890) and M-29A (PTD# 2000990). GNI-03 was tested for 2-year compliance and M-29A was tested for 4-year compliance. As requested, I have included the TIO plot for the last 90 days on M-29A. Please call with any questions. Thank You, Donald Reeves (filling in for Anna Dube) Well Integrity Coordinator 907-659-5102 907-659-5100 xl154 pgr «MIT PBU GNI-03 12-24-06.xls» «MIT PBU M-29A 02-27-06.xls» «M-29A TIO Plot.ZIP» Jim Regg <¡im regg(¿~admin.state.ak.us> Petroleum Engineer AOGCC sGANNED MA'{ 2 9 20tH 1 of! 5/23/2007 4:22 PM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / M pad 02/27/06 Joe Anders Packer Depth Pretest Initial 15Min. 30 Min, WeIlIM-29A I Type Inj. I G TVD I 7,731' Tubing 400 300 280 260 Interval! I P,T.D, 12000990 I Type test I P Test psil 1933 Casing 50 4000 3970 2960 P/F! P Notes: MIT-IA POI OA 90 460 430 410 Weill I Type Inj. I I TVD I I Tubingl Interval! P,T.D. I Type test I I Test psil I Casingl P/FI Notes: I OAI I Weill I Type Inj.1 I TVD I I Tubingl Interval! P,T,D.I I Type test I I Test psil I Casing I P/FI Notes: I OAI Well! I Type Inj.1 I TVD I Tubing Interval I P.T.D,! I Type test I I Test psi! Casing P/FI Notes: OA Well! I Type Inj,1 I TVD I Tubing Interval I P.T.D,! I Type test I I Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring p :::: Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) 2006-0227 _MIT _PBU_M-29A.xls . STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMM~ION RECElveOt ,,;1\3 il & Gas Cons. ... 1. Operations Performed: Anc~@Jt!] Abandon 0 Repair WellO Plug PerforationsD Stimulate I&J Alter Casing 0 Pull TubingO Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownO Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceŒ] 50-029-21904-01-00 7. KB Elevation (ft): 9. Well Name and Number: 56.10 M-29A 8. Property Designation: 10. Field/Pool(s): ADL-028260 Prudhoe Bay Field 1 Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 10773 feet true vertical 9039.0 feet Plugs (measured) CIBP set @ 10640 (04118/2003) Effective Depth measured 10640 feet Junk (measured) Fish below CIBP -- Depth unknown true vertical 8908.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 29 - 109 29.0 - 109.0 1530 520 SURFACE 2665 13-3/8" 72# L-80 28 - 2693 29.0 - 2687.0 4930 2670 PRODUCTION 9495 9-5/8" 47# L-80 27 - 9522 27.0 - 8564.0 6870 4760 LINER 813 7" 29# L-80 8720 - 9533 7859.0 - 8574.0 8160 7020 LINER 2124 2-7/8" 6.16# L-80 8648 . 10773 7796.0 - 9039.0 13450 13890 Perforation depth: Measured depth: 10145-10170,10245-10270,10350-10375, Slotted Liner 10696-10761 True vertical depth: 8690-8690,8692-8695,8715-8724, Slotted Liner 8962-9027 't ,1'\ 1'\t; , >;; ð.~' \~:-T' ,S~n~ "'~C..~ '¡\;'; ... ....... Tubing ( size, grade. and measured depth): 7" 26# L-80 @ 25 - 8498 5-1/2" 17# L-80 @ 8498 - 8720 Packers & SSSV (type & measured depth): 9-5/8" Baker TIW HBBP PKR @ 8573 7" Otis SSSV Landing Nip @ 2098 --'''- <" ';~<"'~~" 12. Stimulation or cement squeeze summary: <¡;'UffiM~ 8Ft o 3 2006 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: --- --- 51 --- -- Subsequent to operation: --- --- 51 --- --- 14. Attachments: 15. Well Class after proposed work: Exploratory(] DevelopmentD ServiceŒ] Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilO GasD WAG ŒI GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or NIA if C.O. Exempt: Contact DeWayne R. Schnorr 306-206 Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature À:A: ~_i- ~ dI.£ Phone 564-5174 Date 9/22/06 SEP 2 7 2006 REPORT OF SUNDRY WELL OPERATION~ Form 10-404 Revised 4/2004 () RIG 1 N A L . . M-29A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/24/2006 ***WELL S/ UPON ARRIVAL*** SET 4.5" MCX (OAL=37", sn=M-42B, RQ-LOCK, .75 BEAN, X-EQ. SUB WI 3/16" PORTS) IN 7" INSERT @2080' SLM.....DRAW DOWN TEST PASSED ***WELL LEFT S/I*** 07/18/2006 CTU #6, Acid Treatment; RIH with WFD PDM and 2.28" 00 Mill. Dry tag liner top at 8645' ctmd (8656' elmd). Turn motor at 1.0 bpm and make it through liner top with no problem. Dry tag btm at 10364' ctmd. Clean out 12' to 10376' ctmd (10387' elmd). Pump ball to shear circ sub. Circulate 300 bbls of 1 % KCL down coil to fluid pack well. Initial injectivity of 1.5 bpm at 1250 psi. Jet 20 bbls 7.5% HCL at 1.0 bpm across perfs from 10376' to 10145' making multiple passes. Flush acid with 200 bbls of 1 % KCL at 3.3 bpm / 1000 psi. POH. FP well to 2500' final injectivity 3.3 bpm at 1300 psi. RDMO. **** Notify PCC/PO of well shut in status **** Job Complete **** 07/17/2006 CTU #6, Fill Clean Out, Acidize Perfs; MU WFD knuckle joint and 1.75" 00 JSN. Bleed WHP from 3300 to 1000 psi. RIH. Tag Inr top at 8638' ctmd. Could not get past after several attempts. POOH. 06/23/2006 BRUSHED SSSV NIPPLE W/4.5 BLB, 3.81 GUAGE RING. SET 4.5 MCX (SER # BPX-99- 2) ISSSV @ 2077'. VALVE WOULD NOT TEST - GOT W/PAD OPERATOR TO SEE IF WE CAN FLOW WELL - WELL WILL NOT INJECT, PULL MCX. ***TURN WELL OVER TO DSO - LEFT WELL SHUT IN*** 06/19/2006 *** WELL FLOWING ON ARRIVAL*** (pre fco) PULLED 4.5" MCX (M-63B) @ 2074' SLM. DRIFT TO DEVIATION W/2.25 CENT & SB, STOP @ 9808' SLM. ***LEFT WELL S/I, NOTIFIED DSO*** FLUIDS PUMPED BBLS 2 Diesel --- PT Surface Equipment 137 SO/50 Methanol 632 1 % KCL Water 152 Extra Slick 1 % KCL Water 20 7.5% HCL Acid 943 TOTAL Page 1 . TREE = W8.LI-EAO= A ClUA TOR = KB. ELBI = BF. ELBI = KOP= Max Angle = Datum MO = OatumTVO= 7-1/16" CNV MeEVOY OTIS 56.11' 28.11 3189' 103 @ 9917' 10581 8800' SS M-29A SAFETY NOTES: SL TD LNR 1 0696' -10761' - 70° @9744'&900@9847' . 2098' -i7" 0115 55SV LANIJNG NP, 10= 5.962" I Minimum ID = 2.37" @ 8648' TOP OF 2-7/8" LINER 8498' -i7" x 5-112" XO I 113-318" CSG, 72#, L-80-BTRS, 10 = 12.347" I7"TBG, 26#, L-80-NSCC, ,0382 bpf, 10= 6.276" TOPOF 5-1/2" TBG I I 8509' -f5-1/2" OTIS XA SLlIJNG SLV, 10 = 4.562" 8573' -f9-5/8" x 5-112" TIW HBBP A<R I TOP OF 2-718" LNR I 8648' 8631' -f5-1/2" OTIS XNP, 10-4.562" I 8648' -fOEROYM:NTSL8 I 8675' -15-1/2" 0115 XN NP, 10 =4.455" , 15-1/2"TBG, 17#,L-80-BTRS, ,0232bpf, 10=4.892" H TOPOF7" LNR H 8720' 8720' 8725' -f7"TIWSIõALASSYW/OSEALS 19-518" CSG, 47#, L-80-BTRS, 10 = 8.681" I I TOP OF 7" BA KER WHPSTOO< I 12-718" LNR. 6.16#, L-80, ,0058 bpt,lO = 2.44" I I 7" MILLOUT WINDOW 9533' - 9540' 10256' 10270' , , , , FISH -(3) 1-1/16" RQLERS IN W8.L LOCA TlON UN<NOWN ÆRFORATIONSUMMARY RB'" LOG: SÆRRY MWO/GR ON 07116/00 ANGLEATTOPÆRF: 89° @ 10145' Note: Rater to Produetion DB tor historieal perf data SIZE SFF NTffiVAL Opn/5qz [)ð. TE 2 6 10145-10170 0 04118/03 2 6 10245 - 10270 0 04118/03 2 6 10350 - 10375 0 04118/03 2-718" 10696 - 10761 Sl TD 07/21/00 2-718"SLTDLNR6.16#, 4 L-80, ,0058 bpt, ID = 2.44" 12-7/8" LI\R, 6.16#, L8o-S1L, .0058 bpf, D =2,37" DATE REV BY COMrÆNTS 02/04189 INTIAL COMPL AS NJECTOR 07/18/00 JCM ClD SIDETRACK 01/15/01 SIS-MD INTIAL REDRA W 03/08/02 RNrrp CORRECTIONS 04/18/03 DlN\lrrLH ADD PERF & CIBP DATE REV BY COMMENTS PRUIJ-tOE BAY UNrr W8.L: M-29A ÆRMIT No: 2000990 APlNo: 50.{)29-21904-01 SEe 1, T11 N. R12E. 2267' FSL & 605' FEL BP Exploration (Alaska) ({ù~"~"'" '[I ~.·..A V:.' fÞ ;\" n U, L6, I.J, '." e e (ill ~ ~ ~ ~ ~ æ ~ / ~K H. MURKOWSKI. GOVERNOR 41.ASIiA OIL AND GAS / CONSERVATION COMMISSION / J 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Don Brown Pad Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 ..' . JON '\ Li '¿\JOG SCANNE.O ... Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, M-29A Sundry Number: 306-206 0,. øC{q clO Dear Mr. Brown: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this-L2day of June, 2006 Enel. \~\7 iu\1" . fifG (;)J'<Ict:; t"l!;/:~c STATE OF ALASKA '1;! . AA Oil AND GAS CONSERVATION COMMI ON APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: Abandon U Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 20 MC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 .4/.~".. nil P_ f'. n Perforate U WaiverU- -.... Stimulate 0 Time Extension 0 Anchorage Re-enter Suspended Well 0 5. Permit to/Drill Number: Exploratory 0 200-0990 / Service ø 6. API Number: / 50-029-21904-01-00 'Plugs (measured): 10640 Burst Suspend U Repair well 0 Pull Tubing 0 9. Well Name and Number: 56.11 KB 8. Property Designation: ADL-028260 11. Total Depth MD (ft): 10773 10. Field/Pools(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool PRESENT WELL CONDITION SUMMARY 'Effective Depth MD (ft): Effective Depth TVD (ft): 10773 9038.73 Size MD / TVD 20" 91.5# H-40 29 109 29 13-3/8" 72# L-80 28 2693 28 9-5/8" 47# L-80 27 9522 27 7" 29# L-80 8720 9533 7859.01 2-7/8" 6.16# L-80 8648 10773 7796.31 ¡-Total Depth TVD (ft): 9038.73 Length 80 109 2687 8564 8574 9039 Casing Conductor Surface Production Liner Liner 2665 9495 813 2124 Perforation Depth MD (ft): 10145 - 10170 10245 - 10270 / 10350 - 10375 10696 - 10761 Slotted Packers and SSSV Type: Perforation Depth TVD (ft): 8689.73 - 8690.17 8692.82 - 8695.49 8714.94 - 8724.07 8962.09 - 9026.73 Slotted 5-1/2" TIW HBBP Packer Tubing Size: 7" 26# 5-112" 17# / Tubing Grade: L-80 L-80 Packers and SSSV MD (ft): 12. Attachments: Descriptive Summary of Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for / '\ Commencing Operations: f3/20/2þ06 16. Verbal Approval: \,./ Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Don Brown Title Pad Engineer Signature ()trY1 £. (Ç -i. ^" JYl Phone 564-4323 Date COMMISSION USE ONLY 13. Well Class after proposed work: Exploratory 0 Development 0 J/J{i..A- II II¿IIA~~ Kt:CEIVED JUN 0 9 2006 ~ ssion M-29A / 1490 5380 6870 8160 13450 IJunk (measured): I UNKLOC Collapse 470 2670 4760 7020 13890 Tubing MD (ft): 27 - 8498 8498 - 8720 8573 Service ø 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 WAG ø / GINJ 0 WINJ 0 Abandoned tJ WDSPL 0 Prepared by Sharmaine Vestal 564-4424 Don Brown 6/6/2006 Conditions of approval: Notify Commission so that a representative may witness SUndryNUmber: ~(Q -'~lo Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: RBDMS 8Fl JUN 1 S 2006 Subsequent Form ReqUired:a-:\i{lO - {o~.¿_ Appw,,' by' U-J( j v ~ COMMISSIONER '-"'" - \./' ,---. APPROVED BY THE COMMISSION Form 10-403 Revised 7/2005 ORIGINAL Date: b-(3.,06 Submit in Duplicate e Wireline Work Request Alaska Wells Group e Var. 4.5 12/14/0 I M-29A I Distribution Wireline (2) l··· .1i2: ~:~~I:.. =J Well: M-29A Date: 06/01/06 lOR 0 AWGRS Job Scope: AFE: PBMPDWL29A-C Engineer: Don Brown WBL Cat. lOR DRIFT/TAG (RATE) Problem Description This well has been on MI injection from 05/06/06 to present and is only taking a very small percentage of MI that is required. / Beware of the potential fo H2S in the returns Initial Problem Review 02/27/06: Swapped from PW to M I 02/27/06: SMG treatment 03/02/06: GC2 Shut-down 05/06/06; P.T.'d and POI. MI Target Rate is 6 mm. seems to be real close to target now. 05/09/06: MI rate to 3 mm 05/09/06 to present: rate varies from 0 mm to 1.2 mm of MI Remedial Plan - WIRELlNE ACTION Obj: Obtain injectivity in the well 1. WL: Drift to TO to ensure that no obstruction exists in the wellbore nor any fill is across the perforations. (Minimum 10 = 2.37" @ 8648' top of 2-7/8" liner) 2. C: FCO (pending 0 & T) 3. C: Spot 20 bbls 7.5% HCI acid across perfs located at 10145' to 10170' MD / and 10245' to 10270' MD and 10350' to 10375' MD. Do not circulate acid to surface. 4. EL: Run IPROF 5. POI e e TREE = WB..LHEAD= A CnJA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 7-1/16"aw McEVOY OTIS 56.11' 28.11' 3189' 103 @ 9917' 10581' 8800' SS M-29A <'" SAFETY NOTES: SL TD LNR 1 0696' -10761' - 70° @ 9744' & 900@ 9847' Q 2098' -17" 011S SSSV LANDING NP, ID = 5.962" I Minimum ID =2.37" @ 8648' TOP OF 2-7/8" LINER 8498' -17" X 5-112" XO I / 113-318" CSG, 72#, L-8D-BTRS, ID = 12.347" 17" TBG, 26#, L-80-NSCC, .0382 bpf, ID - 6.276" ITOPOF5-1/2"TBG I I 8509' -15-1/2" 011S XA SLIDING SLV, ID = 4.562" TOP OF 2-7/8" LNR I 8573' 9-5/8" X 5-112"llW HBBP A<R 8648' 8631' -15-1/2"011SXNP, ID = 4.562" , 8648' -1DEFtOYrvENTSLA3 I 8675' -15-1/2" 011S XN NIP,ID =4.455" I 5-1/2"TBG,17#,L-80-BTRS, .0232bpf,ID=4.892" H TOPOF7" LNR H 8720' 8720' 8725' -17"TIWSEALASSYW/oSEALS I 9-5/8" CSG, 47#, L-80-BTRS, ID = 8.681" I TOP OF T' SA KER WHIPSTOO< 12-7/8" LNR, 6.16#, L-80, .0058 bpf,lD =2.44" I 10696' I 7" MILLOUT WI~OW 9533' - 9540' -1HESCIBP(04/18/03) I TOPOF2-7/8"SLTOLNR -1 10696' 10256' , , , , TOP OF 2-7/8" LNR -1 10761' I ÆRFORA TION SUrvtv1ARY REF LOG: SÆRRY MWD/GR ON 07/16/00 ANGLEA TTOP ÆRF: 89° @ 10145' Note: Refer to Production DB for historical perf data SIZE SA" NTERVAL Opn/Sqz D4.1E 2 6 10145 - 10170 0 04118/03 2 6 10245 - 10270 0 04/18/03 2 6 10350 - 10375 0 04118/03 2-7/8" 10696 - 10761 SL TO 07/21/00 2-7/8" SLTD LNR, 6.16#, L-80, .0058 bpf, ID = 2.44" FISH - (3) 1-1116" ROLLERS IN WB..L LOCLI. 110N U~NOWN 10270' 12-7/8" LNR, 6.16#, L8D-S1L, .0058 bpf, 0 = 2.37" I DATE 02/04/89 07/18/00 01/15/01 03/08/02 04/18/03 REV BY COMrvENTS INITIAL COrvPL AS NJECTOR JCI'v1 cm SIDETRACK SIS-MD INITIAL REDRA W RNfTP CORRECTIONS DM fTLH ADD PERF & CIBP DATE REV BY COrvtv1ENTS PRUDI10E BAY UNIT WB..L: M-29A ÆRMT No: 2000990 API No: 50-029-21904-01 SEC 1, T11 N, R12E, 2267' FSL & 605' FEL BP Exploration (Alaska) .'~-~~>-. ~ '"¡I~ MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2772 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay O5/08/03 Color Well Job # Log Description Date Blueline Prints CD E-02A i c~ .~/~ -7 MEMORY PROD PROFILE 03115/03 1 E-31A o-~--/'-) ~ MEMORY PROD PROFILE 08/08/02 1 M-29A ~._~ ~(~- OC)C~ PDC & TEMPERATURE 04115/03 F-04A ~-~ ,O~- t'~'0 23097 MCNL 03102/03 1 H-21 I ~,(Z~--O~]~ 23074 RST-SIGMA 01/30/03 D.S. 1-32A [~.~o j~[-~ 23083 MCNUBORAX 02102/03 1 1 D.S. 5-06A .~ r-/~'-~h/'~ 23056 RST-SIGMA 01123103 D.S. 7-29B ~-.~"'~ 23096 MCNL 02/15103 1 D.S. 15-38A .~-~0,~'~0/~ 23089 LINER TOP TIE-IN MGPJCCL 02/10/03 1 1 D.S. 15-48A~.~.L~/-OO 5 23098 MCNL 02/19/03 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: MAY 1 $ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-571i ATTN: Beth NO. 2772 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 05/O8/O3 Color Well Job # Log Description Date Blueline Prints CD =-02A I ~ '~ "' i '~'Z MEMORY PROD PROFILE 03/15/03 E-31A _.~.,.~,~ - f ,"/~- MEMORY PROD PROFILE 08/08/02 M-29A ~,~,~ ~'(~ PDC & TEMPERATURE 04/15/03 F-04A ~-~,'_~..~.-- ~_~_~'_) 23097 MCNL 03/02/03 H-21 ~.~'"'7 t 23074 RST-SIGMA 01/30/03 D.S. 1-32A ~'~),~)~-- / ,~5 23083 MCNL/BORAX 02/02/03 D.S. 5-06A l'z~_~--,'"~ .~ 23056 RST-SIGMA 01/23/03 D.S. 7-29B i.~.'~-- ~[~-). 23096 MCNL 02/15/03 IO.s. 15-3SA ~ !~ ! (OL~ 23089 LINER TOP TIE-IN MGPJCCL 02/10/03 D.S. 15-48A I~:~.-. ~-~j~ 23098 MCNL ....02/19/03 . , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: SEP 0 9 2003 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'FrN: Beth MEMORANDUM State of Alaska ~'/~,//;~laska Oil and Gas Conservation Commission TO: Randy Reudrich ~ DATE: May 15, 2003 Commissioner .~.~.~.]3\""' SUBJECT: Mechanical Integrity Tests P.I. Supervisor DS-14, S,M,D Pads 14-17A, 14-21, S-215, M-29A, D-24 FROM: Jeff Jones PBU Petroleum Inspector Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI 14-17AI Type,nj.IG I T.V.D. 18519 I Tubingl 25601 ~1 ~1 ~1 Interval 4 P.T.D.I 2030010 1Type testI P I Test psiI 21301 CasingI 2701 350OI 34401 34201 P/FI P Notes: Test fluid 6.9 bbls 60/40 meth,~'f61 We,,I 14-21 I Type,nj.I S .'IT.v.D.I ~e43 I Tubin~l 3601 30401 30201 30~01,~t~rv~12~/ P.T.D.I 1820860 I TypetestI P /TestpsiI 1500 I Casingl 4001 30401 30101 30001 P/FI P Notes: Test fluid 17 bbls 60/40 methanol. 2 year CMIT TxlA: TBG leak ~ 5566 MD; TTP set ~ 11762 MD WellI S-215 I Typolnj. I S I*.V.D.I ~,~,'l*u~,,,I ~0~01 ~0~01 ~0~01 10201Interval I P.T.D.I 2021540 I TypetestI P I TestpsiI 1500 I Casing I SS01 20401 19001 18401 P/FI P Notes: Test fluid 1 bbl 60/40 methanol WellI M-29AI Type,nj.Is ,,oI ,.01 IntervaI 4 P.T.D.I 2000990 I TypetestI P I TestpsiI 3500 I Casingl 5601 35201 35001 35001 P/FI P Notes: Test fluid 3.2 bbls 60/40 methanol WellI D-24 I Typelnj. I NI T.V.D. I0o41 ~1 Interval O P.T.D.I 1852990 1Type testI P I Test psiI 2010 I Casingl 601 22401 21501 21251 P/FI P Notes: Test fluid 4.6 bbls 60/40 methanol. (MITIA post-patch set on a category B-3 well) We,,I I '^l = 01 22301,ntervaI O P.'r.D.I 1852990 I Type testI P I Test ps~I 3000 I OAI SSI 30001 20001 28401 P/FI P Notes: Test fluid 2.3 bbls 60/40 methanol {MITOA on a cata~or7 B-3 well) Type INJ. Fluid COdes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring I= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALT WATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) May 15, 2003: I traveled to BPXA's Pmdhoe Bay Field wells 14-17A, 14-21, S-215, M-29A and D-24 to witness Mechanical Integrity Tests. JeffRea was the BPXA representative for the tests today. The pretest pressures on each well were monitored and found to be stable and the standard annulus pressure tests were then performed with each well passing the MIT. Well 14-21 has a known tubing leak at 5566' MD and a tubing tail plug was set at 11762' MD to accomplish a successful 2 year interval combination Tx IAMIT for Sundry #399-248. Well D-24 is a BPXA designated catagory B-3 well and both the IA and the OA passed the MIT. Five well houses were inspected with no exceptions noted. Summary: I witnessed successful MIT's on BPXA's Prudhoe Bay Field wells 14-17A, 14-21, S-215, M-29A and D-24. Five well house inspections conducted. M.I.T.'s performed: 6 Number of Failures: _0 Attachments: wellbore schematics (5) Total Time during tests: 7.5 hrs cc; · MIT report form 5/12/00 L.G. MIT PBU 14-17A,14-21 ,S-215,M-29A,D-24 5-14-03 JJ.xls 5/20/2003 TREE= GRAY GEN 3 WELLHEAD = CALICO F ACTUATOR = A XELSON KB. ELEV = 71 BF. ELEV = KOP = 2900' Max Angle = 96@11658' Datum IV[) = 10562' Datum TVD = 8800' SS I 13-3/8" CSG, 72#, L-80, ID = 12.347" Id 2500' IMinimum ID = 2,372" @ 10713' XO TO 2-7/8" STL LINER I I I5-1/2"TBG-IPC, 17#, L-80, 0.0232 bi)f, ID =4.892" H ITOPOF 4-1/2"TBG-IPC Id ITOP OF 7" LNR H 10149' 10149' 102 02' 10185' 10204' 10231' 4-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" Id I 3 -1/2"TBG, #,L-80,.0000bpf, ID=2.992"H 10243' 1024Z 10243' 10492' 10234' 9-5/8"CSG, 47#,L-80, D=8.681" Id ITOP OF WHIPSTOCK Iff ITOPOF WINDOW H FERFORATION SUMMARY REF LOG: 14-17A SPERRY MWD ON 01/17/03 ANGLE AT TOP PERF: 93 @ 11900' Note: Refer to Production DB for historical perf data SIZE SFF INTB~VA L Opn/Sqz DATE 2" 4 11897- 12447 Opn 01/18/03 2" 4 12497- 12547 Opn 01/18/03 1 0492' 10588' 10589' SAFETY NOTES: H2S W ELL 5-1/2"CAMBAL-O SSSV NiP, ID=4.562" I 5-1/2"BAKERLOC SEALASSY I 9-5/8"X 5-1/Z' BKR FERM FKR ] 5-1/2" X 4-1/2" XO I ld3-1/2" DEFLOYMENTSLEEVE, ID= 3.00" I H3-1/2" HOWCO NO-GO XN NIP, D =2.750" I-t H 4-1/2" OTIS XN NIP, ID= 3.725" 4-1/2" BKRSHEAROUTSUBWLEG I 4-1/2" TUBING TAIL Id ELMD TF LOGGED 05/16/91 10350' IdTOPOFCBVIENT I 10559' Id3-1F2" X 3-3/16" XO, D= 2.800"I 10713' Id 3-3/16" X 2-7/8" XO, ID = 2.441" I ITOPOF 4-1/2" 'rBG-IPC Id ITOPOF BRDGE PLUG It 10838' ' I 10848' ~ 4-1/2"TBG-IPC, 12.6#, I-- N-80, 0.0152 bpf, ID = 3.958" I 7" LNI~ 29#, L-80, 0.0371 bpf, ID = 6.184" Id 11400' 3-3/16"LN1~ 6.2#,L-80, Id 10713' I .0000 bpf, ID = 2.80" I I 12~85' H2:7/8"LNR, G.16#,L-80, .0000bpf, D=2.441" I H T^,, I DATE REV BY COMrvlENTS DATE REV BY COMMENTS 05/23/82 ORIGINAL COMPLETION 01/18/03 TMM/TP CTD HORIZONTAL SIDETRACK 02/24/03 TH/KAK PERFCORRECTIONS PRUDHOE BAY UNIT WB_L: 14-17A PERMIT No: 1810210 APl No: 50-029-20562-01 SEC 9 T1 ON R14E4282.68' FEL & 1682.64' FNL BP Exploration (Alaska) TREE= GRAY GEN 2 SAFETY NOTES: WAIVEREDWELL. ***T x IA 14 21 ACTUATOR = AXELSON w FLOWLINE FROZE~I, CORROSION DAMAGE, TWINNED t2,B~ ~ = 71' WITH 14-17. BF. REV = aim ~ KoP = 2800' Datum'rVD = 8800' SS GAS LIFT MANDRELS ST ~ TVD DEC TY~E VLVlLATCH POR~' D~TE ! i~ ~ 355--'--7' 3513 26 Mm ~'~' R--'-~~~ I 3 7~69 6302 52 U~ I RK O~l"~/.~u~ 5 11375 8418 49 MIVH IRK 6 11523 8517 47 MIVH RFP Minimum ID = 3.750" @ 1 1796' I ; ' 4-1/2" CAMCO DB NIPPLE X ~ ~ 11707' ~'~ 9-5/8"X 5-1/2" BKR FB-1 PKR " I I TOP OF 4.1/2" TBG-PC ~ 11725' ~, t 11725'Id i ITOPOF7"LNR~ 11762'--~ PERORATION SUM~ II REF LOG: BHCS ON 08107182 ANGLEATTO¢ PERF: 42 @ 12091' Noto: Rofor to ~odu¢~on DB for historical porf data SiZE I s~:l ~N~RV^L I C~/Sqx I DATE SFt= PAGE 2 FOR PERFORATION 5,!/2,'TBG'Pc'12.6#'L'80,'0152bpf'ID=3.958.' Id 11805' ~ I~~l 12395' I~ ,7"X4'I/2"BKRFB'llSOPKR I ,,, I 124~1' 4-~12" C^ MCO DB ~P ID- 3.887" 4-1/2"~G, 12.6#, C-80, .0152 ~¢, D:3.958" ~ 12351' I 12330' I~ 4'112"rrW/~^KERWLml I. 7"k~R, 29#,k-80,.O371bpf, ID=$.184" ~ la0~' ~ ~'-~1 la055'..I--t 22'PE~GUN&CCL3'118"I , DATE REV BY COMMENTS DA'rE REV BY COMIVlENTS PRUDHOE BAY UNIT ~ 08/13/82 ORIGINAL COIVPLETION , WELL: 14-21 01/25/88 LAST WOF~OVER PERMITNo: 1820860 i02/22/01 SIS-LG REVISION I APINo: 50-029-20756-00 01/08/02 RN/TP CORRECTIONS SEC 9, TION, R14E 1364.03 FEL 4846.25 FNL ,02/20/03 /TLH WAIV ER SAFETY NOTE BP Explo ration (Alas ka) ~,,, DATE REV BY COrvlVlENTS DA'I~ REV BY COMMENTS 08/13/82 ORIGINAL COrv~LETION 01/25/88 LAST WOF~OV ER 02/22/01 SIS-LG REVISION 01/08/02 RN/TP CORRECTIONS 02~20~03 /TLH WAIV ER SAFETY NOTE ,, TREE= CIW 4-1116" 5M S 215 :A CrUAT~ = I IKB. ~ = 72' .................... i i m I lmm m I BF. ~ = 41' K~ = 2238~ Max A~le = ~ ~ 3723' Da~mMD= 6256' ~ ,k~ 114' ~ 20"X~"215.5b/ft, A~WINSULAT~l DammeD= 5000;SS :: I : ~ 976' H TAM ~RTC~R I I i I I ~ ~-l/2".~sx.~..,~= 3.813"I I , Minimum ID = 3.725" ~ 5648" 4-1/2" HES XN NIPPLE , ~ ~' .1/Z' BKR CMD SLID,~ SLV, I W~ ~I/Z' X NiP, ID = 3.813" ~TE: SHI~ SLE~ E DOWN TO OP~, I SHI~ ~ TO CLOSE - 04~8/03 ~ ~ ~ ~ 55~' H7"X*1~"BKRPRMPKR, ID=3.87S' I I I t ~26' ~ 4'1/2" HES X NIP, ID = 3.813"I m~O~ON StarRY I ~51' H ELmW LOmm 03/31/03 I R~ LOG: S~R~ ~D ON 0~0~02 ANGLE AT TOPPE~: 45° ~ 6098' Note: Refer b Production ~ for hist~ical perf data .SEE S~ I INT~VAL ~n/~z~ DATE 2-we" 2 i ~98-6110 O 05/0~03 " ~ 5741' ~ 7"MARK~I~I 2-W8" 2 ~ 6120- 6130 O 05/0~03 " I 2-W8" 2 6150- 6170 O ' 05/0~03 2-7/8" 2 ~40- 6260 O 05/0~03 2-7/8" 2 ~65- 6280 O 05/0~03 . I 62~' I~ 7" MARK~I~ I 2-7/8" 2 ~02- 6342 O 05/0~03 I I 2-7/8" 2 ~35- 6380 O 05/0~03 ~ 2-W8" 2 ~30- ~50 O 05)0~03 '2-W8" 6 ' .6505- ~25 O 03/31/03 ' 2-W8" 2 ~25- ~45 O 05/0~03 i 2-W8" 2 ~85- 6595 O 05/0~03 I m~ ~BY COM~N~ DATE ~BY ~M~S ~A~S UN~ 0~1~02 DAV~K O~GI~LCOM~ON W~: S-215 0~1~03 ~LH COR~C~ON P~ ~: 2021540 0~31/03 CAO~H A~E~ APl ~: 50-02~23107-00 0~0~03 ~S~P ~D/~ ~E~I~S SEC 35, T12N, R12E, 3276' ~L & 4563'W~ 0~2~03 ~/~ NOTEA~EDTO SSLV-55~' 0~0~03 ~M~K A~E~S ~ ~loration (Alaska) PERFORATION SUMMA RY REF LOG: SPERRY MWD ON 08/06/02 ANGLE AT TOPPERF: 45° @ 6098' Note: Refer t~ Production DB for historical perf data .SIZE SPF INTERVAL Opn/S~z DATE 2-7/8" 2 6098 - 6110 O 05/06/03 2-7/8" 2 6120 - 6130 O 05/06/03 2-7/8" 2 6150 - 6170 O 05/06/03 2-7/8" 2 6240- 6260 O 05/06/03 2-7/8" 2 6265- 6280 O 05/06/03 2-7/8" 2 6302- 6342 O 05/06/03 2-7/8" 2 6335- 6380 O 05/06/03 2-7/8" 2 6430- 6450 O 05)06/03 2-7~8" 6 ' . 6505- 6525 O 03/31/03 2-7/8" 2 6525- 6545 O 05106/03 2-7/8" 2 6585- 6595 O 05/06/03 TREE = 7-1/16" CIW W ELLFEA D = McEVOY ACTUATOR = OTIS KB. ELEV = 56,11' BF. ELEV = 28.11' KOP= 3189' Max Angle= 103@9917' DatumMD= 10581 DatumTVD: 8800'SS 113,-3/8" CSG, 72#, L-80-BTRS, ID =12.347" Id Minimum ID = 2.37" @ 8648' TOP OF 2-7/8" LINER 17" TBG, 2~, L-80-NSCC, .0382 bpf, ID= 6.276" Id M-29A SAFETY NOTES: SLTD LNR 10696' - 10761' - 70° @ 9744' & 90° @ 9847' 2098' 2693' ~ 498' 8498' 8498' H7"OTIS SSSV LANDING NP, ID= 5.962" i 8509' I--~5-1/2" OTIS XA SLIDING SLV, ID: 4.562" I ITOP OF 2-7/8" LNR I-~ 864s' 8631' 8648' 8675' 1--~5-1/2" OTIS X NP, ID =4.562"I I--'~DEFLOYMENT SUB I Id5-1/2" OTIS XN NIP, ID =4.455" 5-1/2"TBG, 17#, L-80-BTRS, .0232 bpf, ID= 4.892" Id 8720' ITOPOF7" LNR Id 8720' i 8725' I---~7" TIW SEAL ASSY W/O SEALS 19-5/8"CSG, 47#, L-80-BTRS, ID=8.681" I--~ ITop OF 7' BAKER WHPSTOCK It 12-7~" LNP~ 6.16#, L-80, .0058 bpf, ID= 2.44" I-~ FERFORATION S Urv~laRY REF LOG: SFERRY MWD/GR ON 07/16/00 ANGLEATTOP PERF: 89° @ 10145' Note: Refer to Production DB for historical perf data SEE SPF NTB~VA l Opn/Sqz BATE 2 6 10145- 10170 O 04/18/03 2 6 10245- 10270 O 04/18/03 2 6 10350 - 10375 O 04/18/03 2-7/8" 10696- 10761 SLTD 07/21/00 ,,, 9522' 9530' 10696' 10256' 10270' I 7" MILLOUT WINDOW9533'- 9540' I 10640' IdHES QBP(04/18/03)I I-I I · I,,1-80, .0058 bpf, ID = 2.44" , I DATE REV BY COMMENTS DATE REV BY COrv~VlENTS 02/04/89 INITIAL OOIVPL AS NJECTOR 07/18/00 JCM CTD SIDETRACK 01/15/01 SIS-MD INITIAL' REDRAW 03/08/02 RNfTP CORRECTIONS 04/18/03 DDVV/TLH ADD PERF & ClBP PRUDHOE BAY UNn' WELL: M-29A FERMIT No: 2000990 APl No: 50-029-21904-01 SEC1, T11N, R12E BP Exploration (Alaska) TREE = 6" MCEVOY SA FETY NOTES A CTUA TOE= OTIS ~ 71.67' K(}P = 1650' ~ 10720' lDatum TVDss= 8800' I 13-3/8" CSG, 72#, L80, ID = 12.347"H 2798' I~ ~k GAS LIFT MANDRELS i ST' IVD TVD: DEV TYPE SIZE ,LATCH 6 3388 3119 40 OTIS-LBD 1-1/2"1 RA 5:5412 4619 44 OTIS-LBD 1-1/2" PA 4 7326 5940~ 41 OTIS-LBD 1-1/2' PA _._.~: : 3 8593 6943 33 OTIS-LBD 1-1/2" PA ! Minimum ID: 2.970"@ 7545' ~ 5-1/2" ECLIPSE PACKER ~, I 9768' I I9962' IdELMD'Tr ' DATE NOT AVA ILABL E I I:~RFOPATION SUMM~ RY I:~F LOG: SWS-BI-~S ON 12/26/85 ANGLE AT TOP PERF: 19 @ 10833' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE [] 4" 4 ; 10833- 10843 S 01/01/90 , 3-3/8" 4 I 10856- 10873 O 01/04/91 3-3/8" 4 10878- 10891 O 01/04/91 3-3/8" 4 I 10894- 10900 O 01/04/91 DA'I~ ~ BY I COMMI~ITS DA'I'~ ~ BY COMMENTS F~LDHOE BAY UNII 12/30/85 ORIGINAL COMPLETION Will. k: D-24 05/19/01 RN/IP CORI~CTIONS I PE[~vllI No: 1 05/0~03 I~IM/KK, SET 5-112" ECLIF~SEPKR I APINo: 50-029-21508-00 05/11/03 BJM/KK i SET 5-1/2" ECLIPSE PKR i SEC 23, Tll N, R13E I BP Exploration (Alaska) FERFORATION SUMMA RY REF LOG: SWS-BHCS ON 12/26/85 ANGLE AT TOP PERF: 19 @ 10833' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 10833- 10843 S 01/01/90 4" 4 10856 - 10873 S 01/01/90 4" 4 10878 - 10891 S 01/01/90 3-3/8" 4 10840- 10842 O 03/07/92 3-3/8" 4 10856- 10873 O 01/04/91 3-3/8" 4 10878- 10891 O 01/04/91 3-3/8" 4 10894- 10900 O 01/04/91 DATE REV BY COMMBqTS DATE REV BY COMMENTS 12/30/85 ORIGINAL COMPLETION 05/19/01 RN/TP CORRECTIONS 05/06/03 BJM/KK SET' 5-1/2" ECLIPSEPKR 05/11/03 BJM/KK SET 5-1/2" ECLIPSEPKR Permit to Drill 2000990 MD 10773 -I-VD DATA SUBMITTAL COMPLIANCE REPORT 1/16/2003 Well Name/No. PRUDHOE BAY UNIT M-29A Operator BP EXPLORATION (ALASKA) INC 9039 Completion Dar 12/14/2000 Completion Statu WAGIN Current Status WAGIN APl No. 50-029-21904-01-00 UIC Y REQUIRED INFORMATION Mud Log No Sample N._9_o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint OH / Dataset CH Received Number Comments ~ 5 FINAL G G~R/RR ES 5 FINAL OP/RES 5 FINAL "101 FINAL ~~-tion FINAL 9513 8500 9547 9547 9513 10724 9600 10773 10773 10724 Open 5/1/2001 10123 9513-107;'4 CH 8/18/2000 BL(C) 8500-9600UIC OH 5/1/2001 9547-10773 BL, Sepia OH 5/1/2001 9547-10773 BL, Sepia CH 5/1/2001 ~513-10724 Digital Data CH 5/1/2001 LIS Verification Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis R~.c.~.iv~.d ? Daily History Received? Formation Tops Comments: Compliance Reviewed By: Date: To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 April 27, 2001 MWD Formation Evaluation.Logs · M-29A, AK-MW-00098 M-29A: 2" x 5" MD Gamma Ray Logs · 50-029-21904-01 2" x 5" TVD Gamma Ray Logs · 50-029-21904-01 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic BlVd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED PlAY 0 1 2001 WELL LOG TRANSMITTAL To: State of Alaska April 24, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs M-29A, AK-MW-00098 1 LDWG formatted Disc with verification listing. API#: 50-029-21904-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING ANB RETURNING A COPY OF THE TRANSMITYAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: ,// ' t" STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ~] Gas ~] Suspended [~] Abandoned [~ Service [~1 1~' WAG Iniector. 2. Name of Operator ' ~,A;,R~i~ 7. Permit Number BP Exploration (Alaska), Inc. ¥1[~J~ 200-099 3. Address~'~~~ '"'; 8. APl Number P. O. Box 196612 Anchorage, AK 99519-6612 ,~.~1~ 50-029-21904-01 4. Location of well at surface~ 9. Unit or Lease Name 3011' FNL, 604' FEL, Sec. 1, T11 N, R12E, UM (asp's 628229, 5973344) .r'-~"::"..'."-;:~-:.'T-"~~ ...~..,..:,....._, ;,,.;,,,~ ~ Prudhoe Bay Unit At Top Producing Interval ¢ "; :" ! 10. Well Number 1087' FNL, 4826' FEL, SEC 7, T11N, R13E, UM (asp's 628976, 5970001)i _/_~%:f fO_ '..~.~. i M-29Ai At Total Depth ,' ,, ':',' '. '."; ' 11. Field and Pool 1051' FNL, 4589' FEL, SEC 7, T11 N, R13E, UM (asp's 629212, 5970042) -~- i Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 56.1 feetI ADL 28282 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions July 13, 2000 July 16, 2000 December 14, 2000I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 10773' MD / 9039' TVD 10771' MD / 9037' TVD YES [~] No E]I 2098' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD GR, EWR & Mem CBL w/SCMT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# Surface 110' 30" N/A 13-3/8" 68# L-80 Surface 2693' 17-1/2" 3723 cubic ft AS II & III 9-5/8" 47# L-80 Surface 9522' 12-1/2" 1941 cubic ft Class G 7" 29# Butt 8720' 9533' 8-1/2" 404 cubic ft Class G 2-7/8" 6.16# L-80 8649' 10773' 3-3/4" 20 bbls 15.8 ppg LARC 24. Per~orations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7" 8498' 8573' 10696' - 10761' MD; 8963' - 9027' TVD; Slotted Liner 5-1/2" 8720' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary for details) 27. PRODUCTION TEST Date Injection Production Method of Operation (Flowing, gas lift, etc.) December 18, 2000 (Prod Water Inj) WAG Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I Test Pedod > 5863 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -897 psi 24-Hour Rate > 28. CORE DATA " Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved July 6, 2000 (Permit #200-099) RECEIVED Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Alaska Oil & GasS~It ih duplicate . uornmlsslon Anchorage GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of Sag River Sand 9684' 8616' Top of Shublik 9750' 8658' Top of Sadlerochit 9918' 8747' Top of Zone 4A 10330' 8827' 31. LIST OF ATTACHMENTS Summary of M-29Ai CT Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Prepared by Paul Rauf 564-5799. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: if this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27': Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. REC E tVE Item 28: If no cores taken, indicate "none". Form 10-407 JAN 2 9 Z001 Alaska 0il & Gas Cons. Commission Anchorage M-29Ai DESCRIPTION OF WORK COMPLETED SUPPLEMENTAL COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 7/12/2000 - 7/21/2000: 9/05/2000: 9/07/2000: 9/30~2000 - 10/03/2000: 12/03/2000: 12/04/2000: 12/05/2000: 12/06/2000: 12/07/2000: 12/08/2000: 12/09/2000: 12/11/2000: 12/12/2000: 12/13/2000: 12/14/2000: 12/18/2000 - 1/15/2001' 1/16/2001: Nordic 1 drilled sidetrack. Fish left in hole. (See Nordic 1 Operations summary attachments). RIH w/LIB to 8134' SLM. RIH w/venturi junk basket to 8131' SLM. Nabors 4ES fished motor/mill f/wellbore. Rollars left in wellbore. (See attached Nabors 4ES Operations summary). MIRU service CTU. PT'd equip. RIH w/magnet BHA. RIH w/BHA w/jars & knuckle joint / magnet but unable to get past the top of liner. POOH - tools disconnected & fish left in wellbore. Left disconnect, XO, K J, XO & magnet @ liner top. Weather hold. Weather hold. Tested BOPE. RIH w/fishing BHA & tagged fish @ 8636'. POOH - no recovery. RIH to 10330' CTM & POOH. Recovered fish lost on 12/4/2000. Made 2 attempts to get to BTM w/magnet BHA but unable to get beyond the liner top. RIH w/venturi junk basket & tagged up @ 10306'. POOH - recovered cement & rubber pieces but no rollars or metal. RIH w/motor & mill. Milled cement to 10412' & POOH. Made one run w/venturi junk basket & recovered cement (no rollars or metal). RIH w/magnet. POOH - no recovery. RIH & milled to 10437'. POOH. RIH w/modified venturi junk basket. Worked modified venturi junk basket to 10439' & POOH. Recovered cement w/2 pieces of rubber & gasket. Reran modified venturi junk basket & recovered more cement. RD CTU. MIRU CTU. Tested BOPE. Made one venturi junk basket run to BTM - recovered minor amount of cement. RIH w/motor & mill. Milled to 10469.5' & POOH. RIH & milled to 10529'. Milled to 10539' & POOH. Tested BOPE. RIH & milled to 10650'. POOH. RIH w/3 blade junk mill. Milled through float equip & cleaned out to guide shoe @ 10771' Pumped Biozan pill & chased debris out of well w/2% KCL Water. POOH/w mill. Performed injectivity test: 2 bpm @ 1400 psi. FP'd well. RD CTU. Placed on produced water injection for this period. Averaged 5863 BPD @ 897 psi WHP. Placed on MI injection. Sidetrack Summary Page I RECEIVED JAN 2, 9 2001 AJaska Oil & Gas Cons. Commission Anchorage RECEIVED BP AMOCO Page 1 of 6 JAN 2, 9 7.001 Operations Summa Report Alaska Oil & Gas Cons. Commission Legal Well Name: M-29 Anchorage Common Well Name: M-29 Spud Date: 1/1/1989 Event Name: DRILL+COMPLETE Start: 7/12/2000 End: 7/21/2000 Contractor Name: DOWELL SCHLUMBERGER Rig Release: 7/21/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: ~ I i PROD1 Accept rig 16:00 hrs. NU BOPE. 7/12/2000 16:00- 17:00 1.001RIGU t17:00 19:00 2.00 RIGU i PROD1 Spot equipment. RU. 19:00 - 23:00 4.00 RIGU PROD1 Pressure test BOPE. Witness by John Crisp. Test H2S alarm per i John's request. 23:00 - 00:00 1.00 STWHIP PROD1 'PU inj. Fill coil. Pump dart -- 59.4 bbls. Open well. Dead. 7/13/2000 00:00 - 00:45 0.75 STWHIP PROD1 MU milling BHA: HC DP0261 (S/N 0324223) and Baker string mill on BHI motor. 00:45 - 02:30 1.75 STWHIP PROD1 RIH. Tag cement 9167' CTM. 02:30 - 05:15 2.75 STWHIP PROD1 Mill cement above whipstock 150 FPH. Stall at pinch point. Correct depth to 9533' (-1.5'). 05:15 - 10:20 5.08 s'rWHIP PROD1 Mill window. Begin drilling in open hole at 9541' 10:20 - 10:35 0.25 STWHIP PROD1 Swap to used FIo Pro mud. Drill open hole to 9553' 10:35 - 13:00 2.42 STWHIP PROD1 Ream window area while finish swap to mud 13:00 - 14:45 1.75 STWHIP PROD1 POOH for drilling BHA 14:45 - 15:00 0.25 s'rWHIP PROD1 LD milling BHA 15:00 - 16:00 1.00 DRILL PROD1 Cut off Baker CTC. Install DS CTC. PT @ 3500 psi, 35K 16:00 - 16:35 0.58 DRILL , PROD1 MU drilling BHA: 2.6 deg motor; M-09 bit. 16:35 - 18:00 1.42 DRILL PROD1 RIH with BHA #2 18:00 - 19:00 1.00 DRILL PROD1 Tag up on cement top. PUH 33K, get TF 2.5/2830 46L. Work thru TOC and RIH to flag. Correct depth (-20.5'). RIH tag 9537'. Bounce to 9539'. Can't get thru. Orient TF to 7L. RIH. Tag btm at 9547'. Should be out window. 19:00 - 00:00 5.00 DRILL PROD1 Drill Shublik 20 - 30 FPH. TF = 45L. CTP = 2900 psi; 2.5 BPM. 7/14/2000 00:00 - 01:30 1.50 DRILL PROD1 Continue drilling build and turn in Shublik 20- 30 FPH. Broke into Sad at 9690'. 01:30 - 03:15 1.75 DRILL PROD1 Drill to 9800'. 03:15- 03:30 0.25 DRILL PROD1 Survey. Bad G-totals 03:30- 03:45 0.25 DRILL PROD1 Drill 03:45 - 04:30 0.75 DRILL PROD1 Wiper trip to window. 04:30 - 05:00 0.50 DRILL PROD1 Orient TF. 05:00 - 06:00 1.00 DRILL PROD1 Drill to 9875. 06:00 - 06:30 0.50 DRILL PROD1 PUH and orient for right turn. Way ahead of curve. Decide to POOH for smaller motor. 06:30 - 08:00 1.50 DRILL PROD1 POOH. 08:00 - 09:45 1.75 DRILL PROD1 Change bit, adjust motor to 1.4 deg, add Sperry resistivity tool 09:45 - 11:30 1.75 DRILL PROD1 RIH w/BHA #3 11:30 - 12:25 0.92 DRILL PROD1 Corr -23' to flag. RIH thru window at 32R. Log tie-in to BHCS at 9524' add 9.0'. RIH logging MAD pass to corrected TD at 9883' 12:25 ~ 15:00 2.58 DRILL PROD1 Orient from 110L to right side TF. Can't get any clicks close to btm. Make six trips to window to get close 15:00 - 15:30 0.50 DRILL PROD1 Drilling 30-55'/hr 2.4/2950/55R 15:30 - 16:20 0.83 DRILL PROD1 One more trip to window to get clicks 16:20 - 17:10 0.83 DRILL PROD1 Drilling 60'/hr 2.6/3240/108R 17:10 - 17:40 0.50 DRILL PROD1 Orient back to left 17:40 - 18:30 0.83 DRILL PROD1 Drilling 80'/hr 2.5/3250/91L. Hit tough shale. Drill to 10,040'. Hope it's not Shublik. 98 deg incl. 18:30- 19:00 0.50 DRILL PROD1 Orient 19:00 - 19:45 0.75 DRILL PROD1 Drill to 10080'. 19:45 - 20:00 0.25 DRILL PROD1 Orient around 20:00 - 22:20 2.33 DRILL PROD1 Drill sand to 10240' at 2.5/3000/110L working TF to lower inc to 90 deg in preparation for drop. 22:20 - 23:30 1.17 DRILL PROD1 Wiper trip to window. Work tight shale 9980' - 10060'. Ream multiple passes to clean-up. Printed: 8/10/2000 11:26:25AM ,( RFCFiVFD BP AMOCO JAN ~ 9 2001 Page 2 of 6 Operations Summa Report Alaska Oil & Gas Cons. Commission Anchor3g~ Legal Well Name: M-29 Common Well Name: M-29 Spud Date: 1/1/1989 Event Name: DRILL+COMPLETE Start: 7/12/2000 End: 7/21/2000 Contractor Name: DOWELL SCHLUMBERGER Rig Release: 7/21/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: ............ Bai; ............ Fi~)~':'-T:~3 ....... H';',~i;'~'~;t~'i'~Y-'"~0~l; ...... ~'i~a;; ................... ~e;criPii0n";f Operations 7/14/2000 :23:30 - 23:40 ~. 0.17 DRILL I 'PROD1 ]Orient toolface for drop. 23:40 - 00:00 i 0.33 DRILL I PROD1 Drill 2.6/3100/145R to 10255'. 7/15/2000 00:00 - 01:15 1.25 DRILL PROD1 Drill 2.6/3200/135R to 10347'. 01:15 01:45 0.50 DRILL PROD1 Wiper trip to work shales 9980' - 10060' again. No motor work this time, just real sticky with long stiff tool. Shale plus direction change ~ from right to left is what's gittin us. 01:45 - 03:00 1.25 DRILL PROD1 Drilling 2.7/3300/160L to 10420'. 03:00 - 03:30 0.50 DRILL PROD1 Wiper trip to window. 03:30 - 04:00 0.50 DRILL PROD1 Tie-in at 9523' GR spike. Correct depth (+11') 04:00 - 04:30 0.50 DRILL PROD1 RIH. Work thru shale with motor work. Start displacing well to new FIo-Pro mud. 04:30 - 06:00 1.50 DRILL PROD1 Drill to 10,440'. Drilling break 250 FPH for about 10'. Losses started at 50% but healed-up quickly to full returns. Continue drilling to 10585'. 06:00 - 07:00 1.00 DRILL PROD1 Wiper trip to window. 07:00 - 08:00 1.00 DRILL PROD1 Drilling 40'/hr close to Zone 3 2.5/3100/128L 27 deg 08:00 - 08:30 0.50 DRILL PROD1 Orient around to right side 08:30 - 09:15 0.75 DRILL PROD1 Drilling Zone 3 and dulled bit 09:15 - 09:30 0.25 DRILL PROD1 Wiper to window. Over pulls at 10000' 09:30 - 11:00 1.50 DRILL PROD1 POOH for bit 11:00 - 13:10 2.17 DRILL PROD1 Change bit, motor. PT BHA. Download resistivity data 13:10 - 15:00 1.83 DRILL PROD1 RIH w/BHA #4 15:00 - 16:45 1.75 DRILL PROD1 Have trouble getting thru window. Tie-in. Ream to corr TD @ 10628' w/a few set downs. Orient to Iow side 16:45 - 20:10 3.42 DRILL PROD1 Drilling 25'/hr in Zone 3 2.6/3000/179L Punched thru into Zone 2. Drill to 10740'. 20:10 - 22:30 2.33 DRILL PROD1 POOH for bit. Flag pipe 9400' EOP. 22:30 - 23:00 0.50 DRILL PROD1 Change out bit to DS49. Tri-cone in good shape. 1/16" UG. 23:00 - 23:30 0.50 DRILL PROD1 Load nitrogen acc bottles on injector. 23:30 - 00:00 0.50 DRILL PROD1 RIH with BHA #5. 7/16/2000 00:00 - 01:30 1.50 DRILL PROD1 RIH. Tie into flag. Correct depth (-11'). 01:30 - 01:45 0.25 DRILL PROD1 Log tie-in at 9523' GR spike. No correction. 01:45 - 02:15 0.50 DRILL PROD1 RIH. 02:15 - 02:30 0.25 DRILL PROD1 Drill to 10761' MD (8971' SSTVD). 02:30 - 04:55 2.42 DRILL PROD1 CBU to check for tar. This will take awhile. PUH and work shales. 04:55 - 05:00 0.08 DRILL PROD1 No tar. Drill to 10773'. 05:00 - 09:10 4.17 DRILL PROD1 CBU. Pull up to window and do MAD logging pass down. Found HOT in sample so 10773' is TD. Angle at TD is 1.41 deg 09:10 - 12:25 3.25 DRILL PROD1 Wiper to window and back to TD, no corr. Pump 20 bb1150k fresh FIo Pro pill and leave from TD. Wiper to window 12:25 - 14:00 1.58 DRILL PROD1 POOH for liner. Flag @ 8100' EOP 14:00 - 15:00 1.00 DRILL PROD1 LD drilling BHA. Download resistivity data 15:00 - 15:15 0.25 CASE COMP Safety mtg re: run liner 15:15 - 15:45 0.50 CASE COMP RU liner running tools. MU 2 jts 2-7/8" STL slotted assy 15:45 - 17:45 2.00 CASE COMP MU 67 total jts of 2-7/8" 6.16# L-80 STL solid liner 17:45 - 18:45 1.00 CASE COMP MU Baker CTLRT 18:45 - 19:00 0.25 CASE COMP Crew change/safety mtg 19:00 - 19:15 0.25 CASE COMP Install Baker CTC, pull and PT. Stab inj. 19:15 - 21:00 1.75 CASE COMP RIH. -17' correction at flag. Run to TD 10773'. Recip pipe. 21:00 - 21:30 0.50 CASE COMP Drop 5/8" ball. Set 10k down. Displace. Land ball at 55b. Shear ball seat in CTLRT at 3200 psi and PU to confirm free. 21:30 - 00:00 2.50 CASE COMP Displace well to 2% KCI 3 bpm/2600 psi. 7/17/2000 00:00 - 00:45 0.75 CASE COMP Mix cement. At wt 00:40 hrs. 00:45 - 01:00 0.25 CASE COMP Safety meeting with cementers. Printed: 8/10/2000 11:26:25 AM {'" !' RECEIVED BP AMOCO JAN ?., 9P~l~of6 Operations Summary Report Alaska Oil & Gas Cons. Commission Anchorage Legal Well Name: M-29 Common Well Name: M-29 Spud Date: 1/1/1989 Event Name: DRILL+COMPLETE Start: 7/12/2000 End: 7/21/2000 Contractor Name: DOWELL SCHLUMBERGER Rig Release: 7/21/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: Date [ ~____~ ...... ~ ..... [ I 7/17/2000 101:00-01:301 0.50 CASE I 'COMP ! PT lines to 4000 psi. Pump 20 bbls15.8 G cement. Loadcoildart. ! ; { Pump 2 bbls. Check. Gone. 01:30 - 02:00 0.50 CASE ! COMP Displace cement. Latch into liner wiper plug at 59.2 bbls. Shear at 3600 psi. Displace to LC. Bump at 70.8 bbls at 1000 psi. Bleed to check floats -- OK. Pressure to 500 psi, unsting. Wash back to liner top. 02:00 - 04:00 2.00 CASE COMP POOH. 04:00 - 04:15 0.25 CASE COMP SB inj. LD cementing BHA. 04:15 - 04:30 0.25 EVAL COMP Safety meeting with SWS loggers. 04:30 - 05:15 0.75 EVAL COMP RU SWS for SCMT Icg. 05:15 - 10:00 4.75 EVAL OTHR COMP RIH to 9680'. Attempt to PU and tool was stuck. Work line 3 hrs w/no movement until pulling out of weak point. POOH with E-Line. RDMO SWS 10:00 - 11:20 1.33 FISH OTHR COMP WO fishing tools 11:20 - 12:05 0.75 FISH OTHR COMP MU Baker muleshoe overshot w/1-3/8 grapple, hyd cent, disc. RIH on 33 stds CSH workstring 12:05- 12:30 0.42 FISH OTHR COMP Crew change/safety mtg 12:30 - 14:15 1.75 FISH OTHR COMP !RIH w/CT. Did not see fish at 9680'. RIH to set down in liner at 10228'. Set hook 14:15 - 15:30 1.25 FISH OTHR ~COMP POOH with fish 15:30 - 16:45 1.25 FISH OTHR COMP Standback CSH workstring 16:45 - 17:00 0.25 FISH OTHR COMP LD fishing BHA and fish. Tool looks okay, but missing 3 1-1/4" rollers 17:00 - 18:00 1.00 EVAL OTHR COMP WO SWS to arrive to check out same tool and rerun (backup is being fished on DS 2) 18:00 - 19:00 1.00 EVAL COMP SWS on location. Tool OK. RU and RIH w/SCMT logging tools (w/o roller sub). 19:00 ~ 20:00 1.00 EVAL COMP Log 9600' - 8450'. Good cement across window and up to TOC at 9085'. Corrected liner top 8656'. 20:00 - 20:45 0.75 EVAL COMP POOH w/logging tools. RD SWS. 20:45 - 21:30 0.75 EVAL COMP RU HB&R on IA. Pressure IA to 1500 psi (2 bbls). CAP -- 200 psi. 21:30 - 22:00 0.50 EVAL COMP Pressure well to 3000 psi. Bled off 100 psi in 30 minutes. 22:00 - 22:15 0.25 EVAL COMP Bleed offwell and IA. 22:15 - 22:30 0.25 CASE COMP Safety meeting. 22:30 - 23:30 1.00 CASE COMP MU motor and mill (flat btm 3-bladed cement/junk mill). MU 35 std CSH. 23:30 - 23:45 0.25 CASE COMP Stab inj. 23:45 - 00:00 0.25 CASE COMP RIH 7/18/2000 00:00 - 01:30 1.50 CASE COMP RIH to mill-out float equip. 36k up. Tag and stall 10255' CTM. 01:30 - 03:30 2.00 CASE JUNK COMP Try and mill past 10254'. Multiple stalls, overpulls to 15k -- no steady motor work. Dragging debris up and down over about 5' interval. 03:30 - 05:00 1.50 CASE JUNK COMP Est milling pattern. Mill slow to 10256'. 05:00 - 07:15 2.25 CASE JUNK COMP PR 60 FPH 10256'- 10280, then slowed to 30 FPH. Start 10-bbl sweep at 10268' 07:15- 08:25 1.17 CASE JUNK COMP Steady milling 35-55'/hr 08:25 - 11:00 2.58 CASE JUNK COMP Pump 10 bbl sweep, wiper to TOL. Mill a burr at 10330' 11:00 - 11:30 0.50 CASE JUNK COMP Milling 40'/hr to 10400'. Lots of stalls, wiper to 10320', clean. RIH, set down at 10345', motor stalled 11:30 - 12:00 0.50 CASE JUNK COMP PUH and stuck at mill. Can't go up or down, motor is still stalled 12:00 - 13:15 1.25 CASE JUNK COMP Hold 80K. WO DS mechanics to adjust injector control 13:15 - 14:15 1.00 CASE JUNK COMP Tweek inj. Work pipe to 80k. 14:15 - 14:45 0.50 CASE JUNK COMP Est circ to pump pill and disc ball. Could not pump. Pressured up to 4000 psi, bled slow. 14:45 - 15:15 0.50 CASE JUNK COMP Bleed coil. Pressure backside to 1500 psi. Work pipe. Printed: 8/10/2000 11:26:25 AM BP AMOCO Page 4 of 6 Operations Summa Report Legal Well Name: M-29 Common Well Name: M-29 Spud Date: 1/1/1989 Event Name: DRILL+COMPLETE Start: 7/12/2000 End: 7/21/2000 i Contractor Name: DOWELL SCHLUMBERGER Rig Release: 7/21/2000 Group: COIL Rig Name: NORDIC 1 Rig Number: "-H'~'~S' '~ti'~ i~- -~-o'~l'e-'---~-i~a-~ e- ............................................ -D-~s~-iii~ii-~'~ ~ f-~p-~ ~-~'ii~'S- 7/18/2000 15:15 _ 16:15 1.001 CASE JUNK [ COMP I Try to shear disc in circ sub (should go 4300 - 4700 psi). Pressure to I ' i I i 4500 psi, tripping pump. Repeat while waiting on HB&R. 16:15 - 17:00 0.75 CASE I JUNK COMP RU HB&R. PT lines to 6000 psi. Pressure up coil. Sheared disc at 5500 psi. Circ at 1.2 BPM; 4000 psi thru .2" hole. Work pipe. 17:00 - 18:00 1.00 CASE JUNK COMP Pump pill, load 5/8" delron ball. Displace. Shear at 1600 psi. Est cir 2.2 BPM; 3000 psi. 18:00 - 18:30 0.50,' CASE JUNK COMP Pump 3/4" disc ball 2.5/2650. Shear seat at 3200 psi. PU. Still stuck. 2.2/600. Circulating thru disc 3.7/1400. 18:30 - 19:00 0.50 CASE JUNK COMP Work pipe up to 80klbs - no movement. 19:00 - 20:00 1.00 CASE JUNK COMP Pressure up on annulus to 1500 psi to verify CT integrity - OK. Cont working pipe up to 80klbs with 1500 psi on annulus - no success. Bleed pressure off annulus quickly to surge fluid column. 20:00 - 21:30 1.50 CASE JUNK COMP Continue working pipe up to 70 klbs and down to -10klbs every 15 min. Circ at 3.5 BPM/1700 psi. 21:30 - 23:30 2.00 CASE JUNK COMP Circ at 3.5 BPM/1350 psi. Wait on crude oil to spot for added lubricity and improved weight/force transfer. 23:30 - 00:00 0.50 CASE JUNK COMP Pump 1'7 bbl crude oil to CT and displace to bottom. Put 8 bbl around BHA and rest inside pipe. RECEWE-D JAN Alaska Oil & Gas Cons. Commission Anchorage Printed: 8/10/2000 11:26:25AM ~%LT.~,...,,~_ i V ~,~ BP AMOCO Page 5 of 6 JAN 2 9 2001 Operations Summa Report Alaska 0il & Gas Cons. Commission Legal Well Name: M-29 Anchorage Common Well Name: M-29 Spud Date: 1/1/1989 Event Name: DRILL+COMPLETE Start: 7/12/2000 End: 7/21/2000 Contractor Name: DOWELL SCHLUMBERGER Rig Release: 7/21/2000 Group: RIG Rig Name: NORDIC 1 Rig Number: 7/19/2000 i 00:00 - 02:00 I 2.00 CASE i JUNK i COMP Let crude work around BHA moving I bbl every 30 min and moving ' i pipe. 02:00 - 02:30 0.50 CASE JUNK COMP Pressure backside to 1800 psi and pull up to 80 klbs attempting to free ' I pipe. Hold for 30 min - no success. i02:30 - 04:00 1.501 CASE 'JUNK COMP Continue holding pressure and overpull attempting to free stuck pipe while waiting on acid and pump truck. 04:00 - 06:30 2.50 CASE JUNK COMP Bleed off backside pressure and circ out crude oil pill prep for spotting acid. 06:30 - 07:00 0.50 CASE JUNK COMP PJSM and hazard analysis prior to pumping acid. 07:00- 07:30 0.50 CASE JUNK COMP Mix neutralizer pill. 07:30 - 10:00 2.50 CASE JUNK COMP PT lines to 4000 psi. Pump 15 bbls 12% HCL. Chase. Spot 5 bbls out. Let soak and work pipe for 30 min. Pump another 5 bbls out. Soak and work pipe for 30 min. Pump last 5 bbls out. Soak one hour ~working pipe. No movement. 10:00 - 11:30 1.50 CASE JUNK COMP Circulate 30 bbl high vis pill 4.0/1400 to clean-out any debris settling out of the 7". 11:30 - 15:00 3.50 CASE JUNK COMP At 25 bbls from BU (lead of acid), H2S alarms activated with ppm exceeding 100. SI well and clear personnel on rig (ppm at zero upon exiting). Wait on HazMat crew to sniff rig and cellar. 15:00 - 16:30 1.50 CASE JUNK COMP RU hardline from 2" to M-05's flowline. Safety meeting with crews. Finish offioading vac trucks to clear non-essential personnel. 16:30 - 17:45 1.25 CASE JUNK COMP Circulate 100 bbls to M-05. SI and bleed thru buster. Too much H2S (residual gas bet/2" and packof0. Discuss w/crews. 17:45 - 20:30 2.75 CASE JUNK COMP Call for bleed trailer and a long bleed hose to vent gas off top of well away from rig. 20:30 - 21:00 0.50 CASE JUNK COMP Hold PJSM prior to attempting to bleed gas off. 21:00 - 21:30 0.50 CASE JUNK COMP Open choke and bleed off gas to bleed trailer. 21:30 - 00:00 2.50 CASE JUNK COMP Pump to clear bleed line of gas. Circulate thru open choke. Zero H2S readings. CBU thru choke to confirm no H2S in wellbore. Circ conventionally to flush lines of residual H2S. 7/20/2000 00:00 - 00:15 0.25 CASE :JUNK COMP Safety meeting prior to pressuring IA to 1500 psi and backside to 3000 psi for max allowable pull on CT. 00:15 - 00:45 0.50 CASE JUNK COMP Pressure IA to 1000 psi and walk backside pressure to 3000 psi. lAP climbed to 1450 psi- OK. 00:45 - 01:30 0.75 CASE ~JUNK COMP Pull up to max allowable limit of 65 klbs with 3000 psi collapse force on CT- (80% of yield strength). No pipe movement. Discuss with Anch engr and agree to cease operations and disconnect CT from BHA. 01:30 - 02:30 1.00 CASE JUNK COMP Bleed backside and IA to zero. Load and pump 15/16" ball for disconnect. Land on seat and pressure up to 4900 psi - cannot get enough pressure to shear seat on disconnect w/rig pumps. Need at least 5000 psi on CT. 02:30 - 03:30 1.00 CASE JUNK COMP Wait on HB&R to come out and shear ball seat to disconnect. 03:30 - 04:15 0.75 CASE JUNK COMP RU HB&R and take on seawater for pressuring up. Test lines to 6500 psi. 04:15 - 04:30 0.25 CASE JUNK COMP Pressure up and shear disconnect at 5200 psi. Pull up hole and confirm free - OK. 04:30 - 06:00 1.50 CASE JUNK COMP POH with CT. 06:00 - 06:30 0.50 RIGD JUNK COMP PJSM prior to picking up retrieving tool to pull insert from BVLN. 06:30 - 07:30 1.00 RIGD JUNK COMP MU retrieving tools: 7" GS PT, HDC, Up/Down jars, 17' wt bars, Up/Down accelerator, CV, NRJ, CTC. 07:30-09:00 1.50 RIGD JUNK COMP RIH to insert. 7kup. Latch at 2104'. Pullto20k, hit jars, PUto38k, and pulled free. RIH and set down 2103'. PU clean. POOH. LD BHA Printed: 8/10/2000 11:26:25 AM BP AMOCO Page 6 of 6 Operations Sumrnar~ Report Legal Well Name: M-29 Common Well Name: M-29 Spud Date: 1/1/1989 Event Name: DRILL+COMPLETE Start: 7/12/2000 End: 7/21/2000 Contractor Name: DOWELL SCHLUMBERGER Rig Release: 7/21/2000 Group: RIG 'Rig Name: NORDIC 1 Rig Number: ....... [~;~e- ...... 'l"~'i~-;;'i~-'~--::F;"-I""-~i;U'~:~--[-A~ii'~it~"l-~-;~; ...... I~-I~';'~';-'-'1- ............................................ ~;;C-;i'i~-t-i;-;'-';i'"5~r;i'i;;S- ....................................... I 1 .... ..... 1 ...... 7/20/2000 109:00 - 12:00 3.001 RIGD I ~COMP I Run and LD CSH in singles. 112:00 - 14:30 2.50 ~ RIGD ; i COMP RIH and freeze protect well with MeOH to 2000' (67 bbls). i 14:30 - 15:15 0.75 RIGD 'COMP Blow down coil with N2. 15:15 - 16:30 1.25 RIGD COMP Pu back co to rig I ' 16:30 - 18:30 I 2.00 RIGD COMP ~Suck back fluids from relief line, off load and clean pits. 18:30 - 19:00 0.50 RIGD COMP Safety meeting for night crew to discuss upcoming rig down activities. 19:00 - 00:00 5.00 RIGD COMP Stand injector back and secure for rig move. Continue cleaning pits. Nipple down BOPE and secure for rig move. 7/21/2000 00:00 - 00:30 0.50 RIGD COMP Finish securing BOP for rig move. 00:30 - 01:00 0.50 RIGD COMP Hold pre rig move safety meeting with crew. RELEASE RIG FROM WELL M-29AI AT 0100 HRS ON 07/21/2000. RECEIVED JAN ~ 9 1001 Alaska Oil & Gas Cons. Commission Anchorage Printed: 8/10/2000 11:26:25AM RECEIVED _Page 1 of 1 BP AMOCO JAN 2 9 Z0Ol Operations Summa Report Alaska Oil & Gas Cons. Commission A,chorage Legal Well Name: M-29 'Common Well Name: M-29 Spud Date: 1/1/1989 Event Name: WORKOVER Start: 10/1/2000 End' Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 9/30/2000 06:00 - 13:30 7.50 MOB PRE MOVE FROM A-07 TO M-29. 13:30 - 18:00 4.50 RIGU PRE RIG UP NABORS 4ES ON M-29 WELL. 18:00 - 18:30 0.50 RIGU PRE TAKE ON 300 BBLS SEAWATER IN RIG TANKS. 18:30 - 19:30 1.00 RIGU PRE BERM & R/U 400 BBL TANK. 19:30 - 20:30 1.00' RIGU PRE M/U HARD LINE & PRESSURE TO TANK & TREE. TEST TO 2500 PSI. 20:30 - 22:30 2.00 WHSUR INTERV SET TWC & TEST SAME TO 1000 PSI. 22:30 - 00:00 1.50 WHSUR INTERV N/D X-MAS TREE. CHECK WEAR BUSHING SIZE. 10/1/2000 00:00 - 03:00 3.00 BOPSUF DECOMP N/U BOPE. 03:00 - 04:30 1.50 BOPSUF DECOMP PRESSURE TEST BOPE. LP 250 PSI, HP 3500 PSI, OK. 04:30 - 05:30 1.00 BOPSUF DECOMP PULL TWC VALVE. 05:30 - 06:30 1.00 WHSUR~ DECOMP INSTALL WEAR BUSHING. 06:30 - 08:30 2.00 REST DECOMP P/U O/S FISHING ASSY & 9 * 4 3/4" DCS. (BHA #1) 08:30 - 10:00 1.50 REST DECOMP P/U 3 1/2" DP & RIH TO 2200'. 10:00 - 11:00 1.00 REST , DECOMP CIRCULATE OUT METHANOL FREEZE PROTECTION FLUID. 11:00-16:30 5.50 REST DECOMP P/U31/2"DP&RIHTO8108'. 16:30 - 18:30 2.00 REST DECOMP M/U CIRCULATING HEAD & CIRCULATE WELL. 3 BPM @ 450 PSI ( WATER ROTTEN SMELLING). ClRC OUT 180 BBLS TO TANK. 18:30 - 21:30 3.00 REST DECOMP RIH HOLE & ENGAUGE FISH @ 8145'. WORK PIPE & CIRCULATE OVER FISH. WORKED FISH UP 31', NOT EXCEEDING 80% OF TBG TENSlL STRENGTH. FISH PARTED. 21:30 - 00:00 2.50 REST DECOMP MONITOR WELL 10 MIN. PULL OUT OF HOLE SLOWLY. 4-6K OF DRAG. 10/2/2000 00:00 - 00:30 0.50 REST DECOMP TRIP OUT OF HOLE W/FISH. 00:30 - 02:30 2.00 REST DECOMP PJU FLOOR & L/D FISH. RECOVERED 504.81' OF 1 1/4" TBG. (16 JTS) RECOVERED 3/4" BALL ON IN CIRCULATING SUB. L/D O/S & RE-DRESS SAME. CALC TOP OF FISH NOW @ 8618' 02:30 - 05:00 2.50 REST DECOMP WAIT ON 2 7~8" DP. 05:00 - 07:30 2.50 REST DECOMP LOAD & TALLY 2 7/8" DP. M/U FISHING ASSY #2. 07:30 - 10:00 2.50 REST DECOMP TRIP IN HOLE W/FISHING ASSY #2 ON 3 1/2" DP. 10:00 - 11:00 1.00 REST DECOMP ENGAUGE FISH @ 8616'. ATTEMPT TO CIRCULATE, DP PRESSURED UP. PULL 10K OVER & FISH CAME LOOSE. STILL COULD NOT CIRCULATE.HAD 2K DRAG. 11:00 - 12:00 1.00 REST DECOMP PULL 2 STANDS DP WET. DROP BALL & PRESSURE UP. OPEN PUMP OUT SUB. 12:00 - 16:00 4.00 REST DECOMP POOH W/FISH. ; 16:00 - 19:00 3.00 REST DECOMP L/D FISH, RECOVERED 54 JTS 1 1/4" TBG, MOTOR & MILL. 19:00 - 20:30 1.50 REST DECOMP LID ENTIRE FISHING ASSY. 20:30 - 23:00 2.50 REST DECOMP TIH W/3 1/2" DP & MULESHOE. 23:00 - 00:00 1.00 REST DECOMP POOH & L/D 3 1/2" DP. 10/3/2000 00:00 - 00:30 0.50 REST DECOMP POOH & L/D 3 1/2" DP TO 2200'. 00:30 - 04:30 4.00 REST DECOMP CIRCULATE 70 BBLS DIESEL AROUND WELLBORE & FREEZE PROTECT WELLBORE. ' 04:30 - 07:00 2.50 REST DECOMP CON'T POOH & L/D 3 1/2" DP. TOP OFF PREEZE PROTECTION. 07:00 - 07:30 0.50 REST DECOMP PULL WEAR BUSHING. 07:30 - 08:00 0.50 REST DECOMP INSTALL & TEST TWC TO 2000 PSI, OK. 08:00 - 10:30 2.50 BOPSUF DECOMP BLOW LINES & N/D BOPE. 10:30 - 14:00 3.50 WHSUR DECOMP N/U & PRESSURE TEST X-MAS TREE & HGR TO 5000 PSI, OK. - SLIGHT OIL DRIP ON ACTUATOR VALVE. VALVE HOLDING, HOWEVER SHOULD BE CHECKED BY SERVICE PERSONNEL TO INSURE THERE IS NO PROBLEM. 14:00 - 15:00 1.00 WHSUR DECOMP PULL TWC & INSTALL BPV. SECURE WELL & RELEASE RIG @ 1500 HRS 10-3-00. FINAL RPT. Printed: 11/9/2000 11:57:26 AM North Slope Alaska Alaska State Plane 4 PBU_ WOA M Pad M-29A Surveyed: 16 July, 2000 SURVEY REPORT 1 August, 2000 Your Ref: API.500292190401 Surface Coordinates: 5973344.00 N, 628229.00 E (70° 20' 07.4761" N, Kelly Bushing: 56. loft above Mean Sea Level 148° 57' 34. 7487" W) DRILLING SERV! IZE.~,, A ~J~t.]BURI'Q~ CO~IISANY Survey Ref: svy9903 Sperry-Sun Drilling Services Survey Report for M-29A Your Ref : API-500292190401 Surveyed: 16 July, 2000 North Slope Alaska Measured Depth (ft) Incl. 9502.70 9530.00 9554.79 9589.59 9623.19 9656.19 9700.19 9743.79 9778.79 9813.59 9847.19 9877.03 9917.03 9948.63 9981.83 10011.03 10052.43 10083.83 10113,43 10147.23 10197.83 10231.43 10260.63 10291.43 10322.63 27.430 27.670 32.780 41.660 45.040 50.010 58.27O 68.030 75.710 82.350 92.280 99.910 103.960 103.440 100.260 97.710 96.740 95.950 92.860 89.160 88.280 87.750 83.440 78.410 74.100 Azim. 197.o2o 196.41o 184,28o 171.39o 162.3oo 144.o6o 13o.53o 115.76o lO4.82o 87.640 87.640 87.790 93.070 97.300 lO2.24o lO5.23o 98.OLO 93.070 89.730 83.91o 78.450 71.o5o 73.690 78.620 80.210 Sub-Sea Depth (ft) 8490.59 8514.79 8536.22 8563.95 8588.4O 8610.78 8636.61 8656.37 8667.28 8673.95 8675.52 8672.36 8664.08 8656.59 8649.77 8645.21 8640.00 8636.53 8634.25 8633.66 8634.79 8635.95 8638.19 8643.05 8650.47 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8546.69 8570.89 8592.32 8620.05 8644.50 8666.88 8692.71 8712.47 8723.38 8730.05 8731.62 8728.46 8720.18 8712.69 8705.87 8701.31 8696.10 8692.63 8690.35 8689.76 8690.89 8692.05 8694.29 8699.15 8706.57 3220.06 S 51.68 E 3232.15 S 48.05 E 3244.38 S 45.92E 3265.29 S 46.95 E 3287.68 S 52.25 E 3309.15 S 63.27 E 3335.08 S 87.50 E 3356.06 S 120.03 E 3367.50 S 151.17 E 3371.13 S 184.98 E 3369.75 S 218.48 E 3368.57 $ 248.10 E 3368.85 S 287.21 E 3371.62 S 317.78 E 3377.14 S 349.78 E 3383.99 S 377.80 E 3392.26 S 418.00 E 3395.27 S 449.05 E 3395.99 S 478.55 E 3394.11S 512.27 E 3386.36 S 562.24 E 3377.53 S 594.61E 3368.72 S 622.35E 3361.43 S 651.86 E 3355.86 S 681.64 E 5970125,30 N 628335.73 E 5970113.14 N 628332.31 E 5970100.88 N 628330.39 E 5970079.99 N 628331.78 E 5970057.69 N 628337.45 E 5970036.42N 628348.84 E 5970010.90 N 628373.51E 5969990.48 N 628406.39 E 5969979.58 N 628437.72 E 5969976.52 N 628471.59 E 5969978.48 N 628505.06 E 5969980.17 N 628534.66 E 5969980.55 N 628573.77 E 5969978.30 N 628604.38 E 5969973.33 N 628636.48 E 5969966.96 N 628664.60 E 5969959.39 N 628704.94 E 5969956.91N 628736.04 E 5969956.69 N 628765.54 E 5969959.14 N 628799.22 E 5969967.75 N 628849.05 E 5969977.13 N 628881.27 E 5969986.42 N 628908.86 E 5969994.20 N 628938.24 E 5970000.28 N 628967.92 E Dogleg Rate (°/lOOft) 1.357 32.o31 33.846 21.1Ol 43.344 31.14o 37.545 36.904 52.052 29.554 25.575 16.4o8 13.1o9 17.428 13.362 17.459 15.837 15.347 20.399 10.927 22.067 17.294 22.724 14.674 Alaska State Plane 4 PBU_WOA M Pad Vertical Section (ft) Comment 3063.90 3076.52 3088.85 3108.53 3128.40 3145.70 3163.40 3173.94 3175.76 3169.34 3158.22 3148.41 3137.23 3130.94 3126.85 3125.20 3121.33 3115.12 3107.18 3095.52 3073.48 3055.56 3039.01 3023.41 3009.37 Tie-on Survey Window Point MWD Magnetic Continued... 1 August, 2000 - 3:59 -2- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for M-29A Your Ref: API-500292190401 Surveyed: 16 July, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (fi) (ft) fit) Global Coordinates Northings Eastings (ft) (ft) 10352.43 69.960 86.030 8659.66 8715.76 3352.45 S 709.76 E 10383.43 65.730 88.670 8671.35 8727.45 3351.12 S 738.43 E 10414.83 61.850 88.490 8685.22 8741.32 3350.42 S 766.59 E 10453.43 53.920 87.260 8705.72 8761.82 3349.22 S 799.23 E 10487.23 47.750 86.030 8727.06 8783.16 3347.70 S 825.38 E 10518.83 42.380 83.030 8749.37 8805.47 3345.60 S 847.64 E 10566.63 32.950 75.630 8787.19 8843.29 3340.40 S 876.30 E 10597.23 27.930 68.580 8813.57 8869.67 3335.72 S 891.05 E 10626.72 24.320 60.120 8840.05 8896.15 3330.17 S 902.75 E 10657.32 18.060 61.180 8868.57 8924.67 3324.73 S 912.38 E 10688.92 12.330 63.650 8899.05 8955.15 3320.87 S 919.70 E 10716.32 7.140 62.060 8926.05 8982.15 3318.78 S 923.83 E 10748.52 1.410 120.210 8958.15 9014.25 3318.04 S 925.94 E 10773.00 1.410 120.210 8982.63 9038.73 3318.34 S 926.46 E 5970004.17 N 628995.98 E 5970006.00 N 629024.62 E 5970007.18 N 629052.76 E 5970008.93 N 629085.38 E 5970010.90 N 629111.50 E 5970013.38 N 629133.72 E 5970019.07 N 629162.29 E 5970024.01N 629176.95 E 5970029.76 N 629188.56 E 5970035.35 N 629198.09 E 5970039.34 N 629205.35 E 5970041.51 N 629209.44 E 5970042.28 N 629211.54 E 5970041.99 N 629212.06 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Dogleg Rate (°/100ft) 23.193 15.759 12.367 20.720 18.471 18.271 21.849 20.110 17.564 20.495 18.244 18.965 20.207 0.000 Alaska State Plane 4 PBU_WOA M Pad Vertical Section (ft) Comment 2997.87 2988.20 2979.30 2968,60 2959.49 2950.96 2937.61 2928.81 2920.07 2912.06 2906.23 2903.01 2901.69 2901.82 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 197.020° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10773.00ft., The Bottom Hole Displacement is 3445.24ft., in the Direction of 164.401° (True). Continued... 1 August, 2000 - 3:59 .3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for M-29A Your Ref: API.500292190401 Surveyed: 16 July, 2000 North Slope Alaska Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (~t) (~t) (~t) (ft) 9502.70 8546.69 3220.06 S 51.68 E Tie-on Sulvey 9530.00 8570.89 3232.15 S 48.05 E Window Point 10773.05 9038.73 3318.34 S 926.46 E Projected Suwey Survey tool program From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool. Description (~t) (~t) (fi) (~t) 0.00 0.00 9530.00 8570.89 AK-1 BP_HG - BP High Accuracy Gyro 9530.00 8570.89 10773.00 9038.73 MWD Magnetic Alaska State Plane 4 PBU_WOA M Pad 1 August, 2000 - 3:59 - 4 - DrillQuest 1.05.05 tTt. o0% Schhmberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATrN: Sherrie NO. 418 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date Blueline Sepia Color CD Prints M-29A L4.I C. 20312 SCMT 000717 1 F-04 20294 RST '1~ C~ ~ ~-. 000713 ! 1 1 F-OS l,'~(e "" 07 ~ 20295 EST ~ ~ ~ 000716 1 1 1 F-27 20296 RST ~g~5 000715 1 1 1 F-42 20297 RST ~~~ 000713 I 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 8/11/00 BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED AUG 1 8 2000 Alaska Oil & Gas Cons. Commission Anchorage Schlumberger GeoQuest 3940 Arctic BIvd, Suite 300 Anchorage, AK 99503-5711 ATrN: Sherrie~ Received b~~~'~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, Commissioner THRU: DATE: July 26, 2000 Blair Wondzell, P. I. Supervisor FROM: John Crisp~/o[.~ d~, SUBJECT: Petroleum I~spector H2S Release BPX M Pad Well M-29A PTD 2O0-O99 July 19, 2000: I received a call from Ted Stagg (BP's PBU CTD Operation Team Leader) concerning H2S release from PBU M Pad Well 29A. Mr. Stagg stated that a 15 BBL. 12% HCL acid pill had been spotted across stuck BHA to dissolve cement fines in hopes of freeing stuck BHA. The HCL pill was circulated to surface and H2S gas encountered at the shale shakers 25 BBL's before the acid pill should have been seen @ the shakers. H2S readings reached 100 PPM (max reading on monitor). The well was cased & tested to 3000 psi. prior to cmt. milling operations which led to stuck BHA. It is believed that the source of the H2S was reaction products from the HCL and downhole iron sulfide. I talked w/BP CTD Supervisor John McMullen July 20, 2000 to request his report concerning this H2S release from M-29A. John McMullen's report is attached for reference. SUMMARY: Well M-29A was shut in immediately after H2S alarms were activated. All personnel left the Rig safely. State of Alaska AOGCC required & tested H2S alarms worked in accordance to regulations. BPX is currently reviewing/modifying Rig procedures for handling returned acid to eliminate exposure to H2S on future jobs. Attachments: H2S Release, Well Pad M, 7/19/00 cc; NON-CONFIDENTIAL Subject: H2S Release, Well. Pad M, 7/19/00 Date: Fri, 21 Jul 2000 19:29:50 +0100 From: "PBU, CTD Supervisor" <PBUCTDSupervisor@BP.com> To: "'John Crisp'" <John_Crisp@admin.state.ak.us> CC: "Stanley, Mark J (ANC)" <StanleMJ®BP.com>, "Stagg, Ted O (ORBIS)" <StaggTO@BP.com>, "PBU, Well Ops TL" <PBUWellOpsTL@BP.com>, "PBU, CTD Supervisor" <PBUCTDSupervisor@BP.com> John, As a follow-up to the conversation that both you and Tom Maunder had with Ted Stagg on 7/19/00, here is a summary of events related to the H2S release from Well M-29a (permit %200-099) on 7/19/00. DS/Nordic Rig %1 coil tubing drilling unit had just drilled and completed M-29a sidetrack per approved program. Following the liner cement job and cement bond log, the well was successfully pressure tested to 3000 psi. A motor/mill was then run to mill-up excess cement in the liner. 'During the milling operation, the BHAbecame stuck and could not be pulled free. In hopes of dissolving potential cement fines around the stuck BHA, 15 bbls of 12% HC1 acid was circulated into place. The plans for the returned acid stream were to bypass the shakers/pits and send the stream directly to an outside divert tank where neutralizer had been placed. At about 25 bbls from the lead of the acid returning to surface, the low (10 ppm) and high (20 ppm) H2S alarms in the pits were activated and H2S levels reaChed 100 ppm (max reading on monitor). It is believed that the source of the H2S was reaction products from the HCLand downhole iron sulfide. The well was shut-in immediately and the H2S level dissipated rapidly. .The decision was made to move personnel off the rig and let the rig vent. Upon exiting the rig, the H2S monitor showed 0 ppm . All personnel left the rig safely. Five personnel had symptoms of minor eye/throat irritation and were sent to the medic. They returned to work without treatment or restrictions. A BP Hazmat crew was mobilized to the rig to verify the 0 ppm H2S readings throughout the rig, and operations resumed. Hardline was rigged-up to an adjacent well's flowline and the returned acid was circulated directlyto the Gathering Center. We are currently reviewing/modifying our rig procedures for handling returned acid to eliminate exposure to H2S on future jobs. Please let me know if you need additional information. John C. McMullen BP CTD Supervisor 659-4433 RE: M--29ai, H2S incident Subject: RE: M-29ai H2S incident Date: Thu, 20 Jul 2000 18:39:56 -0500 From: "Stagg, Ted O (ORBIS)" <StaggTO@BP.com> To: '"Tom Maunder'" <tom_maunder@admin.state.ak. us> Tom, An update on yesterdays incident. Several of the rig hands were checked by the medic and all returned to work with no lingering effects. The rig was involved in trying to free a milling assembly that had become stuck while milling 3 rollers that had been left in the 2 7/8" liner by a Schlumberger Cement Bond Logging tool. Since some cement had been milled along with the 3 steel rollers we suspected that cement debris may have been contributing to the stuck milling assembly. After other efforts failed to free the tools, we spotted 15 bbls of 12% HCI to work on the cement debris. We then circulated out the add with the intent to divert the add returns to an open top tank containing acid neutralizer. However, the acid returns came around about 20 bbls earlier than expected. The real problem was that the partially spent acid apparently reacted with remnants of "schmoo" in the 7" tubing. Schmoo is the stuff that is deposited on the tubing walls of produced water injection wells and it contains iron sulfide. As we all should know, HCI reacts with iron sulfide to produce H2S. When the alarms went off the rig crew reacted very well. The well was shut in and the rig was evacuated. A HAZMAT team was summoned to enter and inspect the rig before the rig crew returned. The HAZMAT team found no sign of H2S as the source had been shut in. When work resumed, we ran a line to an adjacent well's flowline and circulated the well to the gathering facility with no further incident. Since the fish was beyond coil tubing's ability to retrieve, we disconnected leaving about 2100 ft of 1 1/4" CS Hydril with a motor and mill in the 2 7~8" liner. We plan to have the workover rig, 4ES, move onto the well and recover the fish. Coiled tubing will then rig back up and complete the liner clean out needed to get the well on injection. Please let me know if further info is needed at this time. Ted From: Tom Maunder[SMTP:tom_maunder@admin. state, ak. us] Sent: VVednesday, July '19, 2000 3:06 PM To: Stagg, Ted 0 (ORBIS) Cc: Stanley, Mark J (ANC); Blair Wondzefl Subject: Re: M-29ai H2S incident <<File: tom maunder, vcf>> Ted, Thanks for the notification. Please keep us informed as more information is available. Tom Maunder "Stagg, Ted 0 (ORBIS)" ~rote: > This is a preliminary report based on brief telephone conversations with Ken 1 of 2 7/2t/00 8:10 AM RE: M-29ai H2S incident > > Smith, PBU Weft Ops Team Leader and John McMuflen, DS/Nordic Coil > Drilling > > Supervisor. At approximately 11:30 to 12:00 hours today the H2S alarms sounded on DS/Nordic 1 coil drilling rig. The vtell was secured and the rig was evacuated. A special HAZMA T crew was dispatched to the rig to enter and evaluate conditions. Four of the ooil drilling crew members felt momemtary dizziness and have been taken in for medical evaluation. Tom Maunder and John Crisp were notified. Further information will be provided as it becomes available. Ted Stagg Coil Drilling Engineer 2 of 2 7/21/00 8:10 AM M-29ai H2S incident Subject: M-29ai H2S incident Date: Wed, 19 Jul 2000 17:43:49 -0500 From: "Stagg, Ted O (ORBIS)" <StaggTO@BP.com> To: '"Tom Maunder'" <tom_maunder@admin.state.ak. us> CC: "Stanley, Mark J (ANC)" <StanleMJ@BP.com> This is a preliminary report based on brief telephone conversations with Ken Smith, PBU Well Ops Team Leader and John McMullen, DS/Nordic Coil Drilling Supervisor. At approximately 11 '30 to 12:00 hours today the H2S alarms sounded on DS/Nordic 1 coil drilling rig. The well was secured and the rig was evacuated. A special HAZMAT crew was dispatched to the rig to enter and evaluate conditions. Four of the coil drilling crew members felt momemtary dizziness and have been taken in for medical evaluation. Tom Maunder and John Crisp were notified. Further information will be provided as it becomes available. Ted Stagg Coil Drilling Engineer 1 of 1 7/19/00 3:18 PM ALASKA OIL AND GAS CONSERVATION CO~llSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re~ Prudhoe Bay Unit M-29A BP Exploration (Alaska) Inc. Permit No: 200-099 Sur. Loc. 2267'NSL, 605'WEL, Sec. 01, T1 IN, R12E, UM Btmhole Loc. 1057'SNL, 4575'WEL, Sec. 7, T1 IN, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Commissioner BY ORDER OF THE COMMISSION DATED this ~ ff-~ day of July, 2000 dlffEnclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .... PERMIT TO DRILL 2O AAC 25.005 la. Type of work [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. 56.11 Prudhoe Bay Field / Prudhoe 3. Address '6. Property Designation c,z;~Z~ ¢, Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL,...04_~ ~7_..~..~,j) 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2267' NSL, 605' WEL, Sec 01, T11 N, R12E Prudhoe Bay Unit At top of productive interval 8. Well Number M-29A Number 2S100302630-277 At total depth 9. Approximate spud date 1057' SNL, 4575' WEL, Sec 7, T11 N, R13E 7/11/2000 Amount $200,000.00 12. Distance to nearest prop_~rty line,~13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) I~.~f"/¥J'/ADL 0¢.4~,..1,~ D.,,'¥1~o',,~ No Close Approach 2560 10866' MD/8.9.7...6' TVD ...... 16. To be completed for deviated wells 17. AnticiPated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9540' MD Maximum Hole Angle 100 o Maximum surface 2283 psig, At total depth (TVD) 8..8.00' / 3..3.....3..9....Psig 18. Casing Program Specifications Setting Depth Size To:) Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage da~a) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2213 8653' 7745' 10866' 8976' 72.5 sx Class 'G' · . .................................... ....................................... ,,,,, ,,, 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10270' feet Plugs (measured) true vertical 9235' feet 0RIGINAL Effective depth: measured 9980' feet Junk (measured) true vertical 9010' feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 138' 138' Surface 2665' 13-3/8" 3723 c.f. 2693' 2693' Intermediate 9494' 9-5/8" 1941 cfi. 9522' 8564' Production Liner 1536' 7" 404 c.f. 8720'-10256' 7859'-9222' RE(,E VE Perforation depth: measured 9656'-9751'; 9761'-9785'; 9809'-9816'; 9890'-9894' JUL 0 5 2000 true vertical 8627'-8934' (six intervals) Ala~8 0il & GaS Cons. Commission An~ofa~' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling PrOgram [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: i-ed Sia'gg, 564-4694 Prepared By Name/Number: Michael Williams, 564-4657 '21. I hereby certify that the forego~g~nd correct to the best of my knowledge ......... f ./ Signed Ted Stagg Title CT Drilling Engineer Date Permit Number '"~..~ "I APl Number .... .~' "~ ..... ~ ........ ' ....... I .............. ~'pprovaii~ata .......... "~'"' r'"~ee""~;¢e;"i';~t;';'': ................................. ~'""' ...... .2._¢..~_~--42~"~ 150' ~;:~2-'~:~ -2/74:~¢'~"-~/ I ,~ ... ~; ~..f~(..2 I for other requirements Conditions of Approval: Samples Required [] Yes ~No Mud Log Required [] Yes ~'No Hydrogen Sulfide Measures J~ Yes [] No Directional Survey Required j~ Yes~No Required Working Pressure for BOPE [] 2K; [] 3K; [] 4K; J~5K; [] 1OK; [] 15K Other: ~ ~'~ ~(~::~ '~*-q:~- by order of .-~ ..~pproved By .... ORIGINAL SIGNED BY Commissioner the commission Date ~ -"" .~. ~...~).~.. Form 10-401 Rev. 12-01-85 D Taylor Seamount Submit In Triplicate BPX M-29ai Sidetrack Summary of Operations: M-29 is being sidetracked to improve injection conformance into Zone 4. This sidetrack will be conducted in two phases. Phase 1: Tubing drift, Set Whipstock, Mill Window: Planned for July 8, 2000. · A Tubing Integrity Test was successful on 7/3/00. · The well will be drifted and a whipstock set at approx. 9540'. · Cement will be downsqueezed past the whipstock to shut off existing perfs. · Service coil will mill the window. Phase 2: Drill and Complete sidetrack: Planned for July 11, 2000. Drilling coil will be used to drill and complete' the sidetrack. Mud Program: · Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 8653' and cemented with approx. 15 bbls cement to bring liner cement approx. 200 ft above the window. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWD Gamma Ray and Resistivity logs will be run over all of the open hole section.. A Memory Cement Evaluation log will be run on e-line across the upper portion of the 2 7/8" liner. Hazards Two faults with lost circulation potential will be crossed. Reservoir Pressure Res. press, is estimated to be 3339 psi @ 8800ss. Max. surface pressure with gas (0.12 psi/ft) to surface is 2283 psi. RECb. 'V.F'_D JUL 0 5 2000 Alaska Oil & Gas Co~s. Commission M-29 Vertical Section 0 8900 8950 9000 9050 9100 500 Path Distance (Feet) 1,000 1,500 2,000 I I deg MD:9540 2,500 I 3,000 I Tot Drld:1326 ft 10866 TD Marker Depths I~Orig Wellbore Kick Off 8,5241ft TVD 9~5401ff MD Deprtr I~KO 3,252 ff MD KO Pt 9,540 MD New Hole 1326 Total MD 10,866 TVD TD 8,976 Curve Curve 2 DLS de~/J00 6 31 Curve $ 31 Curve 4 31 Curve 5 t6 Curve 6 16 Tool Face -40 Length 2O 30 -50 3t5 -90 179 t10 260 180 524 t,328 Drawn: 7/5/00 10:50 Plan Name: Case 102 RECEIVED jUL 0 5 !000 0il & Gas Cons. Co~ 0 500 M-29 1,000 X distance from Sfc Loc -2,500 -3,000 -3,500 -4,000 IWell Name M-29 I CLOSURE IDistance 3,455 ff I Az 163 deg NEW HOLE E/W (X) NIS Kick Off 102 -3,235 TD 997 -3,308 State Plane 629,226 5,970,036 Surface Loc 628,229 5,973,344 DLS 'de~/100 ToolFace Length Curve 1 6 0 20 · Curve 2 31 -40 30 Carve 3 31 -50 315 Curve 4 .31 -90 179 Curve 5 16 110 260 Curve 6 16 180 524 1,328 Drawn: 7/5/00 10:50 Plan Name: Case 102 JUL 0 5 2000 Alaska 0~1 & Gas Cons. Com~ ? TREE: 7 1/16 CIW WELLHEAD: MCEVOY ACTUATOR:OTIS M - 'i Proposed Completion KB. ELEV = 56.11 BF. ELEV = 28.11 13-3/8", #/fi, L-80, BTRS. KOP: 2766' MAX. ~EV. 38.4 7", #Iff, L-80, TUBING ,, TUBING ID: 6.276 CAPACITY: 0.039 BBL/FT 5 1/2" 17#/FT L-80 BTRS. TUBING ID.- 4.892 CAPACITY-0.0232 BBL/FT ITop 2 7/8" approx. 8653' TOP OF 7" I8720. I LINER 9'5/8"'47#1ft'19522' I~ L-80, BTRS Whipstock approx, 9540' MD Sqz. cement to be pumped past the whipstock TOP OF CTC INFLATABLE PKR I 9776' I PERFORATION SUMMARY SIZE SPF I I I I~ a/81 ~ I 9761- 9785 3 3/8 4 9809 - 9816 Iss~s I ~ I 9s~o-9~4 I a a/81 °'51 9874- 9890 [a 3/8 [ 4 [ 9890-9894 I a a/81 4 I ~oo-.~o~ I a a/81 °'51 9902- 9912 133/8~ 4 ]9912-9914 ~33/8~ 4 ~9958-9962 !33/8~ 4 ~9970-9998 INTERVAL OPEN/SQZ'D open open sqzd open sqzd open sqzd sqzd opon sqzd sqzd open II :::::::::::::::::::::::: I SSSV LANDING NIPPLE ( OTIS ) ( 7" )( 5.962" ID) 7 "X 5 1/2" OVER I2098' ] ,JUL 05 20C ,~Jaska Oil & Gas Coos. Cz Anchor~e 8498' I 5 1/2 OTIS '%~," SLIDING SLEEVE ( 4.562" ID ) 8509' · 9 5/8 PACKER TIW (HBBP) J 8573' J __5 1/2 (OTIS)'9(" NIPPPLE I J 4.562 ID 8631' ~'5 1/2 OTIS '~N" NIPPLE I 8675' I I I 4.455 ID TIWSEALASSY. WITH J 8725' J OUT SEALS 2 7/8" liner to be cemented approx, 200 ft above window PBTD 11 i 7" WD O'i;IS' "X" NIPPLE ( 4 1/2 ) ( 3.813" ID) OTIS' "XNI' NIPPLE ..~,',.~ ( 4 1/2) ( 3.725" ID) 805' '.,I. 1~1~'~ .~1;,I.' ' 4 '1/2" TBG TAIL ( TIW )( 3.958 "ID) .<;.,,,,,,,,~!~."' '~FV'"''"'?,iJ~'"" ' ..,i;','. ;' '.~[!i' '~':'~ ' ' ' ' ' ,.?,,, ',!~.?~ :. .//,~.,~:.~ ~{,J, ,~, ,:I':," ' i"'ft, L-80, B;l::hS J .i.~70' I 'D ~m~n 12" 36" LLI _z 22.5" Lubricator 7 1/16" Annular 7 1/16" 5000 psi M-29ai CT Drilling & Completion BOP ~ Blind/Shear ~ 7 1/16" ~ Pipe/Slip ~~ ! ~ ~ ~ 2 3/8" 7 1/16" Pipe SWAB OR MASTER VALVE 2 3/8" I I ,~ 1!_ 0 5 2000 ~ias~,a Oi~ & Gas Cons. ' STATE OF ALASKA ALASK/J, .,. AND GAS CONSERVATION COUl{.' APPLICATION FOR SUNDRY APPROVAL 'ION i1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Operation Shutdown [] Plugging [] Time Extension [] Pull Tubing [] Vadance [] Re-Enter Suspended Well [] Stimulate [] Perforate [] Other Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address' P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2267', NSL, 605' WEL, Sec 01, T11N, R12E At top of productive interval 1022' SNL, 573' WEL, Sec 12, T11N, R12E At effective depth 1157' SNL, 613' WEL, Sec 12, T11N, R12E At total depth 1283' SNL, 641' WEL, Sec 12, T11N, R12E 12. Present Well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service Casing RECEIVED ,1111 052000 ~a~a 0it & ~s Ca~$, Commi~ 10270'feet Plugs(measured) 9235'feet 9980' ~et Junk(measured) 9010'feet Length Size Cemented Structural Conductor 110' 20" Su trace 2665' 13-3/8" 3723 c.f. Intermediate 9494' 9-5/8" 1941 c.f. Production Liner 1536' 7" 404 c.f. 6. Datum Elevation (DF or KB) KBE = 56.11' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number M-29 9. Permit Number 89-02 10. APl Number 50- 029-21904 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool ORIGINAL MD TVD 138' 138' 2693' 2693' 9522' 8564' 8720'-10256' 7859'-9222' Perforation depth: measured 9656'-9751',9761'-9785',9809'-9816',9890'-9894' true vertical 8627'-8934' (six intervals) Tubing (size, grade, and measured depth) 7" L-80 to 8498', 5-1/2" L-80 from 8498' to top of liner @ 8720' Packers and SSSV (type and measured depth) 9-5/8" TIW packer @ 8573', 7" Otis WD packer w/tailpipe assy. 9794'-9807' 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 14. Estimated date for commencing operation ~15. July 08, 2000 16.' If proposal was verbally approved Name of approver Date Approved Status of well classifications as: [] Oil [] Gas [] Suspended Service Contact Engineer Narne/Nurnbec Ted Stagg, 564-4694 Prepared By Name/Numbec Michael Williams, 564-4657 17. I hereby certify that the fore~go~? is true_and correct to the best of my knowledge Signed TedStagg ~ Title CT Drilling Engineer Date ~,~/~-"~-'~ ~ '..' ;-~, .~.,;:~. ~: ~...~i':'.."',:.:, ,.,~L..!,~'/~.::","-:.~1.::' ':'"'~':'"; ': '" '~ ~"::::':'" ' ''~'' '~' ;' ':' ~: .'.v,' ' .'. :~ · :' ' · ' .' ':." Ioo'nc~iti(~n;";f'~PP;$V;'k ' N'otifY C~missi0r~' s0'rep;;s~r~t'aii,~$''~a~'''~i~n;~s' ................... ' .......... r ....... , .......... ,..,..,,...,..., ..., ,. ............ ,,...r,... I Plug integrity __ BOP Test__ Location clearance __ Approval No. ,~ O ~ -- [/7,~' Mechanical Integrity Test Subsequent form required lO- Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate / DATE / ,CHECK NO. H I po, o , o VENDOR ALASKAST 14 O0 DATE INVOICE ! CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET )6;2900 CK062900 100. O0 100. O0 HANDLING INST' PH 1ERRI HUBBLE X46~8 tE ATTACHED CHECK IS IN PAYMENT FOR FFEUS DESCRIBED ABOVE. ml[e]lll_,lll ~ 1 OO. OO 1 OO. OO FiRST':~TIO~Li. BAN K:::~iF AsHEAND CCEVELAND OFflO '" ":':i75~:389 ?':,:!" ::::;:: :; :'::,::"" 412 PAY .. .:?,;,.:,':: ~?,, :. :.?':',' ':,::~.;:, ',?:,:,~:::.;:~,,?:', ,:;;;,,'.,.:,' ,~.,,!:.,,..,,,,.::,:,;;:,::, :.':;:: ':": :::.:. ": DATE '.::~:~::~' ,~"'?" :: ' ::~MOUNT I I , NO~:JVALID A~ER 120 DAYS "' ~:,, :...: ,' .,:.' , .'... :~:' :':.4 ::... ,' , ' :,: .~:~:,~.[ :' ;,,.. ,.. ANCHORAOE AK 99501-3120 WELL PERMIT CHECKLIST FIELD & POOL COMPANY ADMINISTRATION APPR DATE WELL NAME ,~-' Z,~'/~ PROGRAM: exp .. INIT CLASS~~?--" ~t,/~/',,~/' 1. Permit fee attached. 2. Lease number appro~ri;t;.'~, i 3. Unique well name and number .............. '~ .... 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... dev redrll P'/' serv ~' wellbore seg ann. disposal para req GEOLAREA ~) UNIT# /~.//"_~"'"~"~ ON/OFF SHORE ~?~..., ENGINEERING DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY Y N,~ N 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. ,,~/,~ ._~ DATE 33. Seabed condition survey (if off-shore) ............. ~j,~ Y N '~.. ~', 0~> 34. Contact name/phone for weekly progress reports [exploratorj/o/~/~ Y N Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (.E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information. of this nature is accumulated at the end of the file under APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Apr 18 16:57:43 2001 Reel Header Service name ............. LISTPE Date ..................... 01/04/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/04/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PBU MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-00098 S. LATZ C. SEVCIK/J. M-29A 500292190401 BP Exploration (Alaska) Inc. Sperry Sun !8-APR-01 MWD RUN 2 AK-MW-00098 S. LATZ C. SEVCIK/J. MWD RUN 3 AK-MW-00098 S. LATZ C. SEVCIK/J. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 4 AK-MW-00098 S. LATZ C. SEVCIK/J. MAD RUN 4 AK-MW-00098 S. LATZ C. SEVCIK/J. 1 lin 12E 2268 FEL: FWL: ELEVATION IFT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 606 56.11 .00 26.59 # REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 13.375 2693.0 3.750 9.625 9522.0 3.750 7.000 9530.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUB-SEA TRUE VERTICAL DEPTHS (TVDS S) . 3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2-4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBES, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. DATA IN THE INTERVAL 9530' MD, 8515' TVD TO 9876' MD, 8673' TVD WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS WHILE RUNNING IN HOLE BEFORE MWD RUN 2. THIS MAD PASS DATA IS MERGED WITH MWD DA 6. DATA IN THE INTERVAL 9505' MD, 8492' TVD TO 10773' MD, 8982' TVD WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS WHILE PULLING OUT OF HOLE AFTER MWD RUN 4. THIS MAD PASS DATA IS PRESENTED AS A TAIL TO THIS LOG. 7. DEPTH SHIFTING IS WAIVED PER THE E-MAIL FROM D. DOUGLAS FOR DOUG DICKEY OF BP EXPLORATION (ALASKA) INC. TIE-IN TO PARENT WELL CONFIRMED BY BP THROUGH COMPARISON OF THE SCHLUMBERGER CBL DATED 07/17/2000 WITH M-29 OPEN HOLE GAMMA RAY. THE CBL IS ON DEPTH WITH THE PARENT WELL ABOVE THE WHIPSTOCK AT 9530' MD AND WITH THE TOP OF THIS MWD LOG JUST BELOW THE WHIPSTOCK. LOG AND HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 8. MWD RUN 2-4 REPRESENT THE MWD DATA FOR WELL M-29A WITH API% 50-029-21904-01 THIS WELL REACHED A TOTAL DEPTH (TD) OF 10773' MD, 8982' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING CURVES WITH "M" SUFFIX DENOTE MAD PASS DATA $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9513 0 10724 0 RPX 9524 0 10735 5 FET 9524 0 10737 0 RPX 9524 0 10735 5 RPD 9524 0 10735 5 RPM 9524 0 10735 5 ROP 9552 5 10772 5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 9513.0 9884.0 2 9884.0 10635.0 3 10635.0 10740.0 4 10740.0 10781.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RO? MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HRS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Last Name Service Unit Min Max Reading DEPT FT 9513 10772.5 10772.5 ROP MWD FT/H 0 2531.65 10772.5 GR MWD API 16.36 426.3 10724 RPX MWD OHMM 0.17 1636.47 10735.5 RPS MWD OHMM 0.14 1637.58 10735.5 RPM MWD OHMM 0.2 1636.46 10735.5 RPD MWD OHMM 0.12 2000 10735.5 FET MWD HRS 0.2403 17.396 10737 Mean 10142.8 91.9281 52.6369 15.9333 15.547 16.5547 27.41 4.51054 Nsam 2520 2441 2423 2424 2424 2424 2424 2425 First Reading 9513 9552.5 9513 9524 9524 9524 9524 9524 First Reading For Entire File .......... 9513 Last Reading For Entire File ........... 10772.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE SGRC SEMP SEDP SESP SEXP SFXE SRAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ # REMARKS: .5000 START DEPTH 9509 0 9531 0 9531 0 9531 0 9531 0 9531 0 9565 0 STOP DEPTH 10727 5 10746 0 10746 0 10746 0 10746 0 10746 0 10781 0 MAD RUN NO. MAD PASS NO. MERGE TOP 4 1 9509.0 MERGED MAD PASS. $ MERGE BASE 10781.0 # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 ! 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HRS 4 1 68 28 8 Last Name Service Unit Min Max Reading DEPT FT 9509 10781 10781 RAT MAD FT/H 3 3902 10781 GR MAD API 12.39 451.17 10727.5 RPX MAD OHMM 0.17 2000 10746 RPS MAD OHMM 0.15 2000 10746 RPM MAD OHMM 0.11 2000 10746 RPD MAD OHMM 0.06 2000 10746 FET MAD HRS 6.7933 59.1678 10746 Mean 10145 458.801 50 7472 14 5154 15 1893 14 8843 27 1643 37 1704 Nsam 2545 2433 2438 2431 2431 2431 2431 2431 First Reading 9509 9565 9509 9531 9531 9531 9531 9531 First Reading For Entire File .......... 9509 Last Reading For Entire File ........... 10781 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9513.0 9837.5 RPD 9524 0 FET 9524 0 RPX 9524 0 RPS 9524 0 RPM 9524 0 ROP 9552 5 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION {DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 9848 5 9848 5 9848 5 9848 5 9848 5 9883 5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet 14-JUL-00 Insite 0.43 Memory 9876.0 32.8 82.3 TOOL NUMBER PB01532RF3 PB01532RF3 3.750 9530.0 Flo Pro 8.70 65.0 9.0 23000 5.0 .000 .000 .000 .000 .0 129.0 .0 .0 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPH RPD FET Service Order Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 MWD010 FT/H 4 1 68 4 2 MWD010 API 4 1 68 8 3 MWD010 OHMM 4 1 68 12 4 MWD010 OHMM 4 1 68 16 5 MWD010 OHMM 4 1 68 20 6 MWD010 OHMM 4 1 68 24 7 MWD010 HRS 4 1 68 28 8 Last Name Service Unit Reading DEPT 9883. ROP 9883 GR 9837 RPX 9848 RPS 9848 RPM 9848 RPD 9848 FET 9848 Min Max Mean Nsam FT 9513 9883.5 9698.25 742 5 MWD010 FT/H 0 135.64 61.4674 663 5 MWD010 API 19.04 426.3 89.8446 650 5 MWD010 OHMM 0.17 1636.47 34.9102 650 5 MWD010 OHMM 0.14 1637.58 32.866 650 5 MWD010 OHMM 0.2 1636.46 36.657 650 5 MWD010 OHMM 0.12 2000 76.3605 650 5 MWD010 HRS 7.308 17.396 11.9762 650 5 First Reading 9513 9552.5 9513 9524 9524 9524 9524 9524 First Reading For Entire File .......... 9513 Last Reading For Entire File ........... 9883.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPX RPS RPM RPD FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 9838.0 9849 0 9849 0 9849 0 9849 0 9849 0 9884 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: STOP DEPTH 10588 5 10599 5 10599 5 10599 5 10599 5 10599 5 10635 0 15-JUL-00 Insite 0.43 Memory 10635.0 27.9 103.4 TOOL NUMBER PB01532RF3 PB01532RF3 3.750 9530.0 Flo Pro 8.70 65.0 9.0 23000 5.2 .340 .000 .110 .220 74.0 132.0 71.0 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HRS 4 1 68 28 8 Last Name Service Unit Reading DEPT FT 10635 ROP MWD020 FT/H 10635 GR MWD020 API 10588 5 RPX MWD020 OHMM 10599 5 RPS MWD020 OHMM 10599 5 RPM MWD020 OHMM 10599 5 RPD MWD020 OHMM 10599 5 FET MWD020 HRS 10599 5 Min Max Mean Nsam 9838 10635 10236.5 1595 0 2531.65 109.939 1503 16.36 161.24 41.7006 1502 2.62 27.36 9.71885 1502 2.66 27.74 9.96307 1502 2.72 26.6 9.95132 1502 3.73 21.76 10.2434 1502 0.2403 9.6795 1.21413 1502 First Reading 9838 9884 9838 9849 9849 9849 9849 9849 First Reading For Entire File .......... 9838 Last Reading For Entire File ........... 10635 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10589.0 10693 5 RPX 10594 5 10704 5 RPD 10594 5 10704 5 RPS 10594 5 10704 5 RPM 10594 5 10704 5 FET 10600 0 10704 5 ROP 10629 5 10740 0 LOG HEADER DATA DATE LOGGED: 15-JUL-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0.43 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 10740.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 7.1 MAXIMUM ANGLE: 24.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PB01532RF3 PB01532RF3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 3.750 9530.0 Flo Pro 8.65 65.0 9.0 24000 5.4 .170 .000 .140 .180 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4' 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HRS 4 1 68 28 8 70.0 132.0 70.0 68.0 Last Name Service Unit Min Max Mean Nsam Reading DEPT FT 10589 10740 10664.5 303 10740 ROP MWD030 FT/H 0.93 171.17 48.3762 222 10740 First Reading 10589 10629.5 GR MWD030 API 10693 5 RPX MWD030 OHMM 10704 5 RPS MWD030 OHMM 10704 5 RPM MWD030 OHMM 10704 5 RPD MWD030 OHMM 10704 5 FET MWD030 HRS 10704 5 16.84 40.1 23.4314 1.68 12.03 5.83697 1.7 11.84 5.93023 1.69 11.8 5.89643 1.85 11.86 6.15357 0.8141 9.8092 3.95407 210 221 221 221 221 210 10589 10594.5 10594.5 10594.5 10594.5 10600 First Reading For Entire File .......... 10589 Last Reading For Entire File ........... 10740 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ 10694 0 10705 0 10705 0 10705 0 10705 0 10705 0 10740 0 # LOG HEADER DATA DATE LOGGED: STOP DEPTH 10724 0 10737 0 10735 5 10735 5 10735 5 10735 5 10772 5 16-JUL-00 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: Insite 0.43 Memory 10773.0 1.4 1.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PB01532RF3 PB01532RF3 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 9530.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo Pro 8.65 65.0 9.0 24000 5.4 .170 .000 .140 .180 70.0 132.0 70.0 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 RPX MWD040 OHMM 4 1 68 RPS MWD040 OHMM 4 1 68 RPM MWD040 OHMM 4 1 68 RPD MWD040 OHMM 4 1 68 FET MWD040 HRS 4 1 68 8 12 16 20 24 28 Last Name Service Unit Min Max Reading DEPT FT 10694 10772.5 10772.5 ROP MWD040 FT/H 0 1947.15 10772.5 GR MWD040 API 18.01 77.59 10724 RPX MWD040 OHMM 1.92 3.47 10735.5 RPS MWD040 OHMM 1.97 3.6 10735.5 RPM MWD040 OHMM 2.02 3.65 10735.5 RPD MWD040 OHMM 2.11 3.82 10735.5 FET MWD040 HRS 7.1414 13.0703 10737 Mean 10733.3 127.57 25.989 2.59306 2.65855 2.66677 2.78048 7.92919 Nsam 158 66 61 62 62 62 62 63 First Reading 10694 10740 10694 10705 10705 10705 10705 10705 First Reading For Entire File .......... 10694 Last Reading For Entire File ........... 10772.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY .5000 4 1 VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX RAT $ LOG HEADER DATA DATE LOGGED: SOFTWARE 9509 0 9531 0 9531 0 9531 0 9531 0 9531 0 9565 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT. TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): STOP DEPTH 10727 5 10746 0 10746 0 10746 0 10746 0 10746 0 10781 0 16-JUL-00 Insite 0.43 Memory 10773.0 1.4 1.4 TOOL NUMBER PB01532RF3 PB01532RF3 3.750 9530.0 Flo Pro 8.65 65.0 9.0 24000 5.4 .170 .000 .140 .180 70.0 132.0 70.0 70.0 REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD041 FT/H 4 1 68 4 2 RPX MAD041 OHMM 4 1 68 8 3 RPS MAD041 OHMM 4 1 68 12 4 RPM MAD041 OHMM 4 1 68 16 5 RPD MAD041 OHMM 4 1 68 20 6 FET MAD041 HRS 4 1 68 24 7 GR MAD041 API 4 1 68 28 8 Last Name Service Unit Min Max Reading DEPT FT 9509 10781 10781 RAT MAD041 FT/H 3 3902 10781 RPX MAD041 OHMM 0.17 2000 10746 RPS MAD041 OHMM 0.15 2000 10746 RPM MAD041 OHMM 0.11 2000 10746 RPD MAD041 OHMM 0.06 2000 10746 FET MAD041 HRS 6.7933 59.1678 10746 GR MAD041 API 12.39 451.17 10727.5 Mean Nsam 10145 2545 458.801 2433 14 5154 2431 15 1893 2431 14 8843 2431 27 1643 2431 37 1704 2431 50 7472 2438 First Reading 9509 9565 9531 9531 9531 9531 9531 9509 First Reading For Entire File. ......... 9509 Last Reading For Entire File ........... 10781 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/04/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/04/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Library. Scientific Scientific Physical EOF Physical EOF End O,f LIS File