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Home My WebLink About201-201MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-109 PRUDHOE BAY UN BORE L-109 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 L-109 50-029-23046-00-00 201-201-0 G SPT 4144 2012010 1500 2146 2150 2149 2150 396 399 399 399 4YRTST P Bob Noble 6/8/2025 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 UN BORE L-109 Inspection Date: Tubing OA Packer Depth 89 1659 1548 1538IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250617141221 BBL Pumped:3 BBL Returned:1 Thursday, July 24, 2025 Page 1 of 1           Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/18/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250618 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN 07RD2 50733200120200 195113 6/1/2025 AK E-LINE LDL AN 24RD 50733202850100 207170 6/1/2025 AK E-LINE LDL BRU 221-24 50283202020000 225027 5/29/2025 AK E-LINE CBL KALOTSA 10 50133207320000 224147 5/21/2025 AK E-LINE Perf KALOTSA 2 50133206590000 216155 5/25/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/27/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/26/2025 AK E-LINE Perf PBU 06-12C 50029204560300 225022 5/17/2025 HALLIBURTON RBT-COILFLAG PBU 15-32C 50029224620300 217104 5/27/2025 HALLIBURTON RBT PBU D-01B 50029200540200 224155 5/18/2025 BAKER MRPM PBU D-01B 50029200540200 224155 5/18/2025 HALLIBURTON RBT-COILFLAG PBU H-18A 50029208800100 224011 5/14/2025 BAKER MRPM PBU H-18A 50029208800100 224011 5/14/2025 HALLIBURTON RBT-COILFLAG PBU L-109 50029230460000 201201 5/24/2025 HALLIBURTON IPROF PBU L-115 50029230350000 201140 5/19/2025 HALLIBURTON IPROF PBU L-117 50029230390000 201167 5/30/2025 HALLIBURTON IPROF PBU N-07B 50029201370200 223122 6/7/2025 HALLIBURTON RBT PBU S-100A 50029229620100 224083 5/26/2025 HALLIBURTON PPROF-LDL PBU Z-34 50029234690000 212061 5/17/2025 HALLIBURTON IPROF-LDL Please include current contact information if different from above. T40566 T40567 T40568 T40569 T40570 T40571 T40571 T40572 T40573 T40574 T40574 T40575 T40575 T40576 T40577 T40578 T40579 T40580 T40581 PBU L-109 50029230460000 201201 5/24/2025 HALLIBURTON IPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.18 12:03:53 -08'00' 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU L-109 Permit Injection in Orion Oil Pool Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-201 50-029-23046-00-00 CO 471 / CO 505B ADL 0028239, 0028241 7820 Conductor Surface Intermediate Production Liner 6970 80 2693 7783 7723 20" 9-5/8" 7" 6880 29 - 109 27 - 2720 25 - 7808 2294 29 - 109 27 - 2589 25 - 6959 None 470 3090 5410 None 1490 5750 7240 4764 - 7554 4-1/2" 12.6# x 3-1/2" 9.3# L-80 23 - 73314279 - 6725 Structural 4-1/2" Baker Premier Packer 4-1/2" Baker S3 Packer 4596, 4144 7273, 6466 Date: Torin Roschinger Area Operations Manager Tyson Shriver Tyson.Shriver@hilcorp.com 907-564-4542 PRUDHOE BAY 2/7/2024 Current Pools: BOREALIS OIL Proposed Pools: BOREALIS OIL, Schrader Bluff Oil, Orion Pool Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.01.24 14:19:59 -09'00' Torin Roschinger (4662) By Grace Christianson at 3:38 pm, Jan 24, 2024 DSR-1/26/24 CDW 01/24/2024 SFD 1/30/2024MGR01FEB24 10-404 JLC 2/5/2024 2/5/24Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.02.05 14:42:21 -09'00' RBDMS JSB 020624 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU L-109 Permit Injection in Orion Oil Pool Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-201 50-029-23046-00-00 7820 Conductor Surface Intermediate Production Liner 6970 80 2693 7783 7319 20" 9-5/8" 7" 6508 29 - 109 27 - 2720 25 - 7808 29 - 109 27 - 2589 25 - 6959 None 470 3090 5410 7319 1490 5750 7240 4764 - 7554 4-1/2" 12.6# x 3-1/2" 9.3# L-80 23 - 7331 4279 - 6725 Structural 4-1/2" Baker Premier Packer 7273, 6466 4596, 7273 4144, 6466 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, Borealis Pool / Schrader Bluff Oil, Orion Pool Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028239, 0028241 23 - 6519 N/A N/A 5870 1789 100 50 2395 2068 324-035 13b. Pools active after work:Schrader Bluff Oil, Orion Pool 4-1/2" Baker S3 Packer 4596, 4144 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations No SSSV Installed By Grace Christianson at 8:53 am, Mar 28, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.03.28 05:36:33 -08'00' Torin Roschinger (4662) RBDMS JSB 040424 WCB 2024-07-09 DSR-4/12/24 ACTIVITY DATE SUMMARY 3/17/2024 T/I/O =1913/27/364 Assist Slickline Pumped 100 bbls amb DSL down tbg for SL. ***job continued to 03-18-24*** 3/17/2024 ***WELL INJECTING ON ARRIVAL*** RAN 2' x 1-7/8'' WB, 2.69'' CENT, 3-1/2'' TEL, 1.75'' S.BAILER, LOC TTL @ 7324' SLM / 7331' MD (+7 corr) TAG TD @ 7524' SLM / 7531' MD (soft & sticky btm, sample of creamy schmoo) 23' FILL FROM BTM OPEN PERFS RAN KJ, 3-1/2'' BLB, 2.80'' G-RING, BRUSHED X-NIPS @ 7298' MD & 7319" MD ***LRS PUMPED DOWN TBG 100bbls diesel*** ***WSR CONT ON 3-18-24*** 3/18/2024 ***job continued from 02-17-24*** Pressure test TBG Plug to 2500 psi with 1.9 bbls DSL TBG lost 113 psi in 1st 15min and 40 psi in 2nd 15 min for a total loss of 153 psi in 30 min test. Pad Op notified upon departure. FWHP = 75/21/351 3/18/2024 ***WSR CONT FROM 3-17-24*** SET 2.813'' PX-PLUG BODY w/ 18'' FILL EXT (4x3/16'' ports, 43'' lih) IN X-NIP @ 7319' MD SET P-PRONG (1.75'' fn, 80'' lih) IN 2.813'' PLUG BODY @ 7319' MD LRS PERFORMED PASSING ''PRESSURE TEST'', TBG 2508#psi 1ST 15MIN (- 113) 2ND 15MIN (-40) (pass, see lrs log) PULLED ST#1 RK-DGLV FROM 4753' MD ***PULLED w/FULL COLUMN DIESEL, SURFACE PRESS. 800#psi*** SET ST#1 RK-MAX FLOW @ 4753' MD ***SET w/FULL COLUMN DIESEL, SURFACE PRESS. 800#psi*** ***WELL LEFT S/I ON DEPARTURE*** Daily Report of Well Operations PBU L-109 RAN KJ, 3-1/2'' BLB, 2.80'' G-RING, BRUSHED X-NIPS @ 7298' MD & 7319" MD SET ST#1 RK-MAX FLOW @ 4753' MD )()( g) PULLED ST#1 RK-DGLV FROM 4753' MD RAN 2' x 1-7/8'' WB, 2.69'' CENT, 3-1/2'' TEL, 1.75'' S.BAILER, LOC TTL @ 7324' @ SLM / 7331' MD (+7 corr) TAG TD @ 7524' SLM / 7531' MD (soft & sticky btm, () sample of creamy schmoo) SET 2.813'' PX-PLUG BODY w/ 18'' FILL EXT (4x3/16'' ports, 43'' lih) IN X-NIP @ 7319' MD Open New Pool Well: L-109 PTD: 201-201 API: 50-029-23046-00-00 Well Name:L-109 Permit to Drill:201-201 Current Status:Operable, WAG API Number:50-029-23046-00-00 Estimated Start Date:February 2024 Estimated Duration:2days Regulatory Contact:Abbie Barker Revision:0 First Call Engineer:Tyson Shriver (907) 564-4542 (O)(406) 690-6385 (M) Second Call Engineer:Leslie Reavis (907) 777-8326 (O)(907) 440-7692 (M) Current Bottom Hole Pressure:2,954 psi @ 6,600’ TVDss 8.61 ppg | SBHPS 4/12/2021 (Kuparuk) Max Anticipated Surface Pressure:2,294 psi (Based on 0.1 psi/ft gas gradient) Last SI WHP:500 psi 5/19/2023 Min ID:2.813” @ 7,260’ MD X-Nipple Max Angle:36 deg @ 4,298’ MD Last Tag:7,535’ MD SL Tag 4/1/2023 Brief Well Summary: L-109 (PTD# 201-201) was completed in 2002 with the ability to inject in both the Schrader Bluff (Orion Pool) and Kuparuk (Borealis Pool). On completion, the well only injected in the Borealis Pool. A recent single lateral OA producer, L-231, and multizone producer, L-205A, were drilled near L-109 resulting in value for establishing Schrader Bluff injection in L-109. The proposed plan is to plug the Borealis Pool and WAG inject into the Orion Pool only. If there are ever plans to comingle inject into the Orion and Borealis pools, a separate request will be submitted. Objective: Isolate the Kuparuk (Borealis Pool) with a tubing tail plug. Install waterflood regulator valves in the waterflood mandrels across from the Schrader Bluff (Orion Pool) interval. WAG inject into the Schrader Bluff. Current Status: Operable WAG (on PWI), Kuparuk (Borealis Pool) Water Injection Rate: ~1,800 bpd Water Injection Pressure: ~1,440 psi Recent Integrity: 07/21/2021 – AOGCC MIT-IA Passed to 1,628 psi 07/17/2021 – AOGCC MIT-IA Passed to 2,279 psi 04/02/2015 – PPPOT-IC Passed to 3,500 psi WBL Steps: 1 S SET PLUG IN X-NIPPLE AT 7,319’ MD, PRESSURE TEST PLUG, PULL AND INSTALL WFRVS IN ST #1 & 2 2 F ASSIST SL LOAD WELL AND PRESSURE TEST Procedural Steps: Slickline 1. Drift well to PBTD with TEL and sample bailer. a. Note fill depth in AWGRS. 2. Brush nipples in tubing tail. a. At WSS discretion to perform full B&F as needed. 3. Load well and set plug in X-nipple at 7,319’ MD a. If there are difficulties setting plug, can set plug in X-nipple at 7,298’ MD (still below production packer at 7,273’ MD). WAG inject into the Orion Pool only. Open New Pool Well: L-109 PTD: 201-201 API: 50-029-23046-00-00 4. Pressure test plug to 2,500 psi 5. Set catcher on top of plug. 6. Pull dummy valves from St #1 (4,753’ MD) & 2 (4,694’ MD). 7. Install WFRVs in St #1 & 2. Fullbore 1. Assist SL with B&F as directed. 2. Load well with 1% KCl or Seawater and diesel freeze protect. 3. Once plug is set, pressure test well to 2,500 psi Attachments – x Current Wellbore Schematic x Proposed Wellbore Schematic x Map & AOR x Sundry Change Form Open New Pool Well: L-109 PTD: 201-201 API: 50-029-23046-00-00 Current Wellbore Schematic: Open New Pool Well: L-109 PTD: 201-201 API: 50-029-23046-00-00 Proposed Wellbore Schematic: Open New Pool Well: L-109 PTD: 201-201 API: 50-029-23046-00-00 Map: Agree. SFD Op e n N e w P o o l We l l : L - 10 9 PT D : 2 0 1 - 20 1 AP I : 5 0 - 0 2 9 - 2 3 0 4 6 - 0 0 - 0 0 AO R : We l l N a m e P T D A P I D i s t a n c e / S t a t u s To p o f O i l P o o l (S B O A , M D ) To p o f O i l P o o l (S B O A , T V D ) To p o f C m t ( M D ) T o p o f C m t ( T V D ) Zo n a l Is o l a t i o n C o m m e n t s P B U L - 1 0 9 2 0 1 - 2 0 1 5 0 - 0 2 9 - 2 3 0 4 6 - 0 0 - 0 0 0 ' / I n j e c t o r 4 7 6 4 ' 4 2 7 9 ' 4 0 1 0 ' 3 6 6 7 ' C l o s e d 2- s t a g e c e m e n t j o b w i t h E S ce m e n t e r a t 5 4 2 0 ' M D . F i r s t at t e m p t a t 2 n d s t a g e j o b wa s u n s u c c e s s f u l . A sq u e e z e j o b w a s p e r f o r m e d (3 5 b b l s 1 5 . 8 p p g C l a s s ' G ' ) an d b u l l h e a d e d 2 0 b b l s 1 5 . 7 p p g A S 1 d o w n t h e O A . U S I T ( 6 / 1 4 / 2 0 0 2 ) s h o w s c e m e n t ac r o s s t h e S c h r a d e r , T O C a t 40 1 0 ' M D . P B U L - 0 1 2 0 1 - 0 7 2 5 0 - 0 2 9 - 2 3 0 1 1 - 0 0 - 0 0 11 9 0 ' / P & A ' d f o r Si d e t r a c k 46 5 0 ' 4 3 5 4 ' s u r f a c e s u r f a c e C l o s e d Si n g l e s t a g e c e m e n t j o b . Pu m e d 3 5 6 b b l s 1 0 . 7 p p g AS I I I f o l l o w e d b y 4 3 b b l s Cl a s s ' G ' . 4 8 b b l s c e m e n t co n t a m i n a t e d s p a c e r a n d 5 0 go o d c e m e n t r e t u r n e d t o su r f a c e d u r i n g c e m e n t j o b . Th e w e l l b o r e w a s ab a n d o n e d f o r s i d e t r a c k i n 20 1 4 . P B U L - 1 0 8 2 0 2 - 1 0 9 5 0 - 0 2 9 - 2 3 0 9 0 - 0 0 - 0 0 1 0 3 5 ' / I n j e c t o r 4 9 5 8 ' 4 3 5 0 ' 4 4 4 0 ' 3 9 6 7 ' C l o s e d 2- S t a g e c e m e n t j o b w i t h E S ce m e n t e r a t 5 6 2 9 ' M D . O n 2n d s t a g e , p u m p e d 6 1 . 5 bb l s 1 5 . 6 p p g C l a s s ' G ' . U S I T ( 6 / 3 0 / 2 0 0 2 ) s h o w s c e m e n t ac r o s s t h e S c h r a d e r . T O C a t 44 4 0 ' M D . P B U L - 1 1 0 2 0 1 - 1 2 3 5 0 - 0 2 9 - 2 3 0 2 8 - 0 0 1 3 5 0 ' / P r o d u c e r 5 3 8 1 ' 4 2 3 9 ' 4 1 8 9 ' 3 4 6 4 ' C l o s e d Pu m p e d 1 0 9 b b l s 1 2 . 0 p p g Li t e C R E T E . N o l o s s e s d u r i n g jo b . B a s e d o n 3 0 % e x c e s s , T O C i s e s t i m a t e d a t 4 , 1 8 9 ' M D . P B U L - 2 2 1 2 0 8 - 0 3 1 5 0 - 0 2 9 - 2 3 3 8 5 - 0 0 - 0 0 8 5 0 ' / I n j e c t o r 5 3 9 3 ' 4 2 9 7 ' 3 5 8 0 ' 3 0 6 2 ' C l o s e d Pu m p e d 7 0 . 2 b b l s C l a s s ' G ' . No l o s s e s d u r i n g j o b . U S I T ( 4 / 7 / 2 0 0 8 ) s h o w s c e m e n t ac r o s s t h e S c h r a d e r . T O C a t 35 8 0 ' M D . A r e a o f R e v i e w P B U L - 1 0 9 Okay. SFD Okay. SFD pick: TOC 4462' MD. barrels Okay. SFD Okay. SFD pick: TOC 3710' MD. A gr e e. Hi l c o r p N o r t h S l o p e , L L C Hi l c o r p N o r t h S l o p e , L L C Ch a n g e s t o A p p r o v e d W o r k o v e r S u n d r y P r o c e d u r e Da t e : J a n u a r y 2 4 , 2 0 2 4 Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l L - 1 0 9 Su n d r y # : An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a t e d t o th e AO G C C b y t h e w o r k o v e r ( W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a n g e . St e p Pa g e Da t e P r o c e d u r e C h a n g e HNS Pr e p a r e d By ( I n i t i a ls ) HN S Ap p r o v e d By ( I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : As s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : Fi r s t C a l l O p e r a t i o n s E n g i n e e r D a t e From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Commingled injection between Borealis and Schrader Bluff/Orion oil pools. Date:Thursday, October 19, 2023 1:50:49 PM Attachments:image001.png L-109 PTD 2012010 From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Wednesday, April 26, 2023 5:20 PM To: Brodie Wages <David.Wages@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Kyndall Carey <Kyndall.Carey@hilcorp.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: Commingled injection between Borealis and Schrader Bluff/Orion oil pools. Brodie, Oliver, and Kyndall, I can’t remember for sure, but I think I may have told one of you that commingling injection between the Borealis and Schrader Bluff/Orion Oil Pools would require a separate order from the AOGCC to authorize that. This is not actually the case. Rule 6 of AIO 26B, which covers the Schrader Bluff/Orion Oil Pool states: Condition d is met because both pools already have injection orders, so the two criteria that need to be satisfied to authorize commingled injection between the Schrader Bluff/Orion Oil Pool and the Borealis Oil Pool (really, between the Schrader Bluff/Orion Oil Pool and any other oil pool with an existing injection order that an injector may pass through) are just conditions a & b, which require demonstration of mechanical isolation between the pools and an approved injection allocation methodology. Probably the cleanest way to handle this would be to submit a letter showing mechanical isolation has been achieved, either for an existing well that has already been setup for future downhole commingled injection (like L- 109 and others) or after converting a well to a commingled injector setup and proposing an allocation methodology and we’ll follow up with an admin approval authorizing the commingled injection. Alternatively, if there’s a methodology or a few methodologies you’d like to use for the allocation we can amend Rule 6 to add the approved allocation method(s) to the order and not have to deal with that going forward. Again, sorry if I misled you previously, just wanted to make sure I set the record straight in case you were proceeding down a different path. And, if I was just hallucinating that I recent discussed this with one of you and actually haven’t then just look at this as a road map should you decide to commingle Borealis and Orion injection in the future. Regards, Dave Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: L-109 (PTD# 201201)Self report of misinjection into Schrader Bluff- Orion pool Date:Thursday, October 19, 2023 1:50:26 PM Attachments:EXTERNAL RE L-109 (PTD# 201201) Pool injection clarification .msg From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Friday, April 21, 2023 3:49 PM To: Roby, David S (OGC) <dave.roby@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: L-109 (PTD# 201201)Self report of misinjection into Schrader Bluff- Orion pool Dave, Chris, Regarding the attached communication we had yesterday pertaining to authorized injection strata for well L-109 (PTD# 201201), Hilcorp North Slope, LLC is self-reporting unauthorized injection into the Schrader Bluff- Orion pool from 4/3/23-4/21/23, with a total injected volume of 32340 BBLs produced water. Immediately after your clarification email yesterday L-109 was shut-in and freeze protected. This incident is currently under investigation and we will provide you with the incident summary, root cause analysis and actions to prevent recurrence once the investigation is complete. Let me know if you have any questions at this time. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Roby, David S (OGC) To:Oliver Sternicki Subject:[EXTERNAL] RE: L-109 (PTD# 201201) Pool injection clarification Date:Thursday, April 20, 2023 4:10:08 PM Attachments:image001.png L-109 Kup only injection sundry.pdf Hi Oliver, Actually, despite what I told Brodie, I don’t think you can inject in the Schrader/Orion unless you approve a sundry application first. The reason for this is that on August 20, 2002, BPXA submitted a sundry application to put the well on injection in the Borealis after a short period of pre-production. According to the cover letter that came with the application “The well is planned to be used for Kuparuk service only. Once the Orion Field has approved PA, Tract Operations and/or Pool Rules, dual injection maybe requested for this wellbore.” On the 22 nd we approved the sundry with a COA of “Injection approved for Kuparuk only.” According to our production records the well has never injected in the Schrader and according to our well file Schrader injection has never been requested. So, since it was approved as Kuparuk only we’ll need to approve a sundry permit in order to also authorize Schrader/Orion injection. Attached is the sundry referenced above. Regards, Dave Roby (907)793-1232 From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, April 20, 2023 3:35 PM To: Roby, David S (OGC) <dave.roby@alaska.gov> Subject: L-109 (PTD# 201201) Pool injection clarification Dave, I need clarification on authorized injection into a multiple pool completion. According to data miner L-109 (PTD#201201) show up under the Borealis Pool for injection: The well was completed in Borealis and Orion. Are we authorized to inject into the Orion? Thanks, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. jpppg ()p j MEMORANDUM TO: Jim Regg �2f ��13�Zrz( P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 11, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC L-109 PRUDHOE BAY UN BORE L-109 Src: Inspector Reviewed By: P.I. Suprv? NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-109 API Well Number 50-029-23046-00-00 Inspector Name: Jeff Jones Permit Number: 201-201-0 Inspection Date: 7/21/2021 Insp Num: mitJJ210810170225 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-109 Type Inj W, TVD 4144 Tubing 744 - 749 - 743 742 PTD 2012010 Type Test SPT' Test psi 1500 IA 179 1750 1641 1625= BBL Pumped: 3.8 BBL Returned: 3.8 OA 420 423 - 423 423 ' Interval 4YRTST !P/F P Notes: One well inspected, no exceptions noted. Wednesday, August 11, 2021 Page I of 1 S • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg r DATE: Thursday,July 20,2017 P.I.Supervisor 1"(11 7("1'? SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. L-109 FROM: Lou Laubenstein PRUDHOE BAY UN BORE L-109 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry T— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-109API Well Number 50-029-23046-00-00 Inspector Name: Lou Laubenstein Permit Number: 201-201-0 Inspection Date: 7/17/2017 " Insp Num: mitLOL170718143357 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-109 • Type Inj W 'TVD 4144 ' Tubing 1617 - 1617 • 1618 1618 - --- ------ ------ PTD 2012010 ' Type Test SPT Test psi 1500 - IA 122 2380 - 2290 2279 - BBL Pumped: 3.1 • BBL Returned: 1.9 OA 490 - 493 - 494 494 Interval 4YRTST P/F P ✓ Notes: %MOOp (,-,, ' 2 PAP Thursday,July 20,2017 Page 1 of 1 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU L-109 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-201 50-029-23046-00-00 7820 Conductor Surface Intermediate Production Liner 6970 80 2693 7783 7319 20" 9-5/8" 7" 6508 29 - 109 27 - 2720 25 - 7808 29 - 109 27 - 2589 25 - 6959 None 470 3090 5410 7319 1490 5750 7240 4764 - 7554 4-1/2" 12.6# x 3-1/2" 9.3# L-80 23 - 7331 4279 - 6725 Structural 4-1/2" Baker Premier Packer 4596, 4144 4596, 7278 4144, 6471 Torin Roschinger Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY, BOREALIS OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028241 23 - 6519 N/A N/A 1781 1932 100 100 1510 1636 N/A 13b. Pools active after work:BOREALIS OIL Baker S3 Packer 7278, 6471 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Kayla Junke at 2:58 pm, Apr 21, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.04.21 13:30:21 -08'00' Torin Roschinger (4662) DSR-4/26/23WCB 11-28-2023 RBDMS JSB 042523 ACTIVITY DATE SUMMARY 4/1/2023 ***WELL INJECTING ON ARRIVAL*** BRUSHED 3-1/2 & 4-1/2'' TUBING OUT TTL (105bbls diesel /1900psi) RAN TEL & 1-3/4'' SAMPLE BAILER, LOCATE TT @ 7326'SLM/7331'MD, TAGGED FILL @ 7535'MD (19' of bottom perfs covered) SET 3-1/2'' RMX PLUG BODY @ 7319'MD (Injectivity 1bpm= 1850psi / 2bpm=1980psi) SET DMY RMX PRONG IN RMX BODY @ 7319'MD PRESSURE TEST= TBG=2300psi loss 39psi 5min / negative test= TBG=100psi gain 90psi 5min PULLED ST#2 RK-DMY @ 4,694' MD (TBG PSI=625psi) ***WSR CONT ON 4-2-23*** 4/1/2023 T/I/O = 1296/54/466 T = 120* Assist SL (WATERFLOOD REGULATOR) Pumped 3 bbls 60/40 meth and 110 bbls 180* Diesel down TBG for B&F. Pumped 20bbls diesel for a baseline injectivity before SL set plug.Freeze protected FL and S-riser w/ 6bbls 60/40. ***job continued to 04-02-23*** 4/2/2023 ***job continued from 04-01-23*** Pump 75 bbls diesel down tbg as directed by slickline. FWHP's= 700/20/400 4/2/2023 ***WSR CONT FROM 4-1-23*** SET RK-WFR(1318 bpd) IN ST 2 AT 4694' MD SET 2.813 XX-PLUG X-NIPPLE AT 7,258' SLM/7260'MD(negitive test failed- inj wing leaking) PULLED RK-DMY WRF FROM ST#1 AT 4753'MD (620psi s/i pressure W/ column of diesel) SET RK-WFR(1318 bpd) IN ST#1 AT 4753' MD PERFORM INJECTIVITY TEST 1BPM 1600PSI, AT 2BPM 1850PSI, 2500PSI @ 2.25BPM NEGATIVE TEST= TBG= 100PSI GAIN 125PSI IN 5 MIN EQ & PULL 3-1/2'' XX-PLUG FROM X-NIP AT 7260'MD(RMX remains) ***WELL LEFT S/I ON DEPARTURE*** Daily Report of Well Operations PBU L-109 (RMX remains) @( SET 3-1/2'' RMX PLUG BODY @ 7319'MD The RMX plug is correctly shown in the new WBS, below. -WCB • TE OF ALASKA • ' ALASKA OIL AND CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other 0 BRIGHTWATER Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waived] Time Extension ❑ TREATMENT Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development p Exploratory ❑ 4 201 -2010 3. Address: P.O. Box 196612 Stratigraphic Service El 6. API Number: Anchorage, AK 99519 -6612 . 50- 029 - 23046 -00 -00 8. Property Designation (Lease Number) : _ 9. Well Name and Number: ADLO- 028241 . L -109 10. Field /Pool(s): c PRUDHOE BAY FIELD / BOREALIS OIL POOL 11. Present Well Condition Summary: Total Depth measured 7820 feet Plugs (measured) None feet true vertical 6970.16 feet Junk (measured) None feet Effective Depth measured 7723 feet Packer (measured) 4596 7273 feet true vertical 6880.44 feet (true vertical) 4144 6466 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 29 - 109 29 - 109 1490 470 Surface 2693' 9 -5/8" 40# L -80 27 - 2720 27 - 2589 5750 3090 Production 7783' 7" 26# L -80 25 - 7808 25 - 6959 7240 5410 Production Liner I 'n ,V Liner �' Perforation depth: Measured depth: SEE ATTACHED - " " _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 23 - 4653 23 - 4190 3 -1/2" 9.3# L -80 4653 1 4190 - 6519 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker Premier Packer V 4144 4 -1/2" Baker S -3 Perm Packer sir 3 6466 12. Stimulation or cement squeeze summary: VA Intervals treated (measured):�,i1 Ntr' 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: 4,062 1,899 Subsequent to operation: 3,980 1,894 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory 0 Development ❑ Service' IS Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: - Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP❑ SPLUG ❑ 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: NA Contact Joe Lastufka Printed Na e •e Lastufk. Title Petrotechnical Data Technologist Signat re M 1 Phone 564 -4091 Date 11/2/2011 NE I Form 10 -404 Revised 10/2010 � r/ � / Submit Original Only L -109 201 -201 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L -109 5/30/02 PER 4,764. 4,794. 4,278.7 4,302.82 L -109 5/30/02 PER 4,844. 4,880. 4,343.13 4,372.23 L -109 5/30/02 PER 4,894. 4,910. 4,383.59 4,396.58 L -109 5/30/02 PER 4,962. 4,985. 4,438.99 4,457.86 L -109 5/30/02 PER 5,024. 5,065. 4,490.02 4,524.06 L -109 5/30/02 PER 5,096. 5,108. 4,549.95 4,560.01 L -109 6/17/02 STC 4,596. 7,273. 4,143.85 6,466.48 L -109 7/16/02 APF 7,484. 7,514. 6,659.97 6,687.66 L -109 7/16/02 APF 7,524. 7,554. 6,696.89 6,724.58 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET • FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 411 ^ ~ �� N� • �� u�� DESCRIPTION OF COMPLETED �� u��n ��' WORK NRWO ��l�l��~�� nm��vv�� m�^��'�� EVENT �%�� v��n�� SUMMARY *+4. ' ~ � e �� I � �4 �� 10/3/2011 l7|A0=1950/1200/450 Temp=Hot (Brightwater . Mod) Pumping brightwater chemicals down TBG while on water injection @ 40000 bwpd. Pumped 0 gal. EC9360A ( Surfactant) Average of 0 gph for 24 hrs. Pumped a ;total of since todofpn�ect > t f Do| gal. � Pumped O gal. EC9378A( Polymer ) Average of 0 gph for 24 hrs. Pumped a total of 0 gal. since start of project. 10/4/2011;T7|k0=1950/1200/450 Temp=Hot (Brightwater ` Sweep Mod) ,Continue injection �eoUon��4OOO 'bvvd o . .. Pumped 103 gal. EC9360A Surfactant) Average 31 gph for hrs. Pumped a ' ( --` total of 103 gal. since start of project. Pumped Average 114uoh�r3hra.Pumpeda . gal. ( ^ ' gph total of 380 gal. since start cm ab�oforo»ct _ —� � - 1 /5 11' |J CONTINUED FROM 10-04-11 WSR ---- --- - � 771/O=1850/1200/450 Temp=Hot (Brightwater ` —'— Continue pumping chemicals down TBG while on water injection 8D4OOU| `bvvod .. ;�m��05g�.��(�u ��.�mm�e' ( . Surfactant) total of 0O8oa�m�000�adofpr�mot. |Pumo��g�.E��(P�ym�) ��gm�1�o�1�24h�.Pu�� \ i Pumped ( ' gph total of3484oa�n�ceoto�ofpr�act gal. JOB CONTINUED ON 10-6-11 WSR 1 VG/2O1.T OE C NT|NUEDFROW1 10-05-11 WSR / T/KO=1950/1200/450 Temp=Hot (Brightwater Reservoir Sweep Mod) :Continue pumping brightwater chemicals down TBG while on water © 4000 | ,_ Pumped 659 gal. EC9660A( Average total of14G7gai since start ' project. Surfactant) gph Pum��g��(��\ Average of 1�gph��.�mp� � . ( . abda ofG2S7ga.o�caota�ofpr�e�t ,JOB CONTINUED ON 10-07-11 WSR _' 10/7/2011:J[3CONT|NUEO FROM 10-08-11 WSR l7|K0=1950/1200/450 Temp=Hot (Brightwater Reservoir Sweep Mod) Continue pumping brightwater chemicals down TBG while on water injection @ 4000 bwpd. |Pumpad 726 gal. EC9660A ( Surfactant) Average of 3Ogph for 24 hrs. Pumped o| total of 2193 gal. since start of p 'ect. ,Pumped 3O10 gal. EC9378A( Polymer ) Average of 12Ggph for 24 hrs. Pumped i a total of 9313 gal. since start of project JOB CONTINUED ON 10-8-11 WSR • • 10/8/2011JOB CONTINUED FROM 10 -07 -11 WSR 1T /I /0= 1950/1200/450 Temp =Hot (Brightwater Reservoir Sweep Mod) Continue pumping brightwater chemicals down TBG while on water injection @ 4000 bwpd. =Pumped 676 gal. EC9660A ( Surfactant) Average of 28 gph for 24 hrs. Pumped a ;total of 2869 gal. since start of project. Pumped 2761 gal. EC9378A ( Polymer) Average of 122 gph for 24 hrs. Pumped a total of 12074 gal. since start of project + E Safety Drills :JOB CONTINUED ON 10 -09 -11 1 0/9/201 1 1JOB CONTINUED FROM 10 -08 -11 WSR T /I /0= 1950/1200/450 Temp =Hot (Brightwater Reservoir Sweep Mod) Continue pumping brightwater chemicals down TBG while on water injection @ 4000 lbw d Pumped 688 gal. EC9660A ( Surfactant) Average of 28.6 gph for 24 hrs. Pumped a total of 3557 gal. since start of project. Pumped 3051 gal. EC9378A ( Polymer) Average of 127 gph for 24 hrs. Pumped a total of 15125 gal. since start of project JOB CONTINUED ON 10 -10 -11 WSR 10/10/2011 'JOB CONTINUED FROM 10 -09 -11 WSR T /I /0= 1950/1200/450 Temp =Hot (Brightwater Reservoir Sweep Mod) ' PCC lost water injection, shut down for 8 hrs. ;Continue pumping brightwater chemicals down TBG while on water injection @ 4000 bwpd. Pumped 435 gal. EC9660A ( Surfactant) Average of 27 gph for 16 hrs. Pumped a I total of 3992 gal. since start of project. Pumped 2121 gal. EC9378A ( Polymer) Average of 132 gph for 16 hrs. Pumped 'a total of 17246 gal. since start of project 'JOB CONTINUED ON 10 -11 -11 WSR 10/11/2011JOB CONTINUED FROM 10 -09 -11 WSR T /I /0= 1950/1200/450 Temp =Hot (Brightwater Reservoir Sweep Mod) 'Continue pumping brightwater chemicals down TBG while on water injection @ 4000 bwpd. 'Pumped 658 gal. EC9660A ( Surfactant) Average of 27.8 gph for 24 hrs. Pumped a total of 4650 gal. since start of project. 'Pumped 2996 gal. EC9378A ( Polymer) Average of 125.5 gph for 24 hrs. Pumped a total of 20242 al. since start of project Job continued on 10 -12 -11 WSR • • 10/12/2011 T/I/0= 2090/1150/450 Temp =Hot (Brightwater Reservoir Sweep Mod) ;Continue pumping brightwater chemicals down TBG while on water injection @ 4000 bwpd. Pumped 13 gal. EC9378A ( Polymer) Pumped total of 13 gallons in 1 hr with =average rate of 13 gph, Total pumped since start of job,20255 gallons for average of 123 gph for whole job. All Polymer pumped away Pumped 56 gal. EC9360A ( Surfactant) Pumped total of 56 gallons in 2 hr's with average rate of 28 gph , Total pumped since start of job 4706 gallons for average of 28.3 gph for whloe job Brightwater Treatment complete on L -109, RDMO ;Valve positions at departure Swab -C, WV,SSV,MV - 0, IA and OA OTG , Fuseable ?cap installed on SSV. FWHP's= 1970/1150/450 i 3 FLUIDS PUMPED GALS 20,255 EC9378A (POLYMER) 4,706 EC9660A (SURFACTANT) 24,961 TOTAL FLUIDS PUMPED BBLS 2 METH 3 DIESEL 5 TOTAL • A TREE =- 4- 1/16" 5M CIW WELLHEAD = 11" FMC 5M SAFETY NOTES: A REQUIRES A SSSV i t. _ACTUATOR = . N/A - 09 WHEN ON MI. KB. ELEV = _ 76.4' B ELEV = 53.6' KOP = 400' :::-1 1017' H9-5/8" TA M PORT COLLAR Max Angle = 36 @ 4298' Datum MD = 7502' Datum TV D = 6600' SS ' I I 2261' H4-1/2" HES X LANDING NIP, ID = 3.813" 1 19-5/8" CSG, 40 #, L -80, ID = 8.75" I-1 2720' 1 - 4111 lk GAS LIFT MANDRELS ST MD T V D D E V TYPE VLV LATCH PORT DATE ' 5 3803 3495 34 KBG -2 DMY BK -5 0 09/07/02 Minimum ID = 2.813" @ 7260' L 4 4415 3998 36 KBG -2 DMY BK -5 0 06/17/02 3 -1/2" HES X NIPPLE 3 4520 4082 36 KBG -2 DMY BK -5 0 09/07/02 WATER FLOOD MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 4694 4223 37 MMG -W DMY RK 0 06/17/02 1 4753 4270 37 MMG -W DMY RK 0 06/17/02 II II I 4585' 1-- 14 - 1/2" HES X NIP, ID = 3.813" 1 /12 1 X 4 -1/2" BKR PREMIER PKR, ID = 3.870" I I4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 4653' 1 I 4653' H4-1/2" X 3 -1/2" XO, ID = 2.992" I 0 I I I ( 7260' 1 HES X NIP, ID = 2.813" 1 B 2 7273' I X 4 -1/2" BKR S -3 PKR, ID = 2.992" 1 I I 7298' -1 3 -1 /2" HES X NIP, ID = 2.813" 1 13-1/2" TBG, 9.3 #, L -80, .0087 bpf, ID = 2.992" 1 — I 7331' I I I 7319' 1- 13 -1/2" HES X NIP, ID = 2.813" PERFORATION SUMMARY / ■ I 7331' H 3 -1/2" WLEG, ID = 2.905" 1 REF LOG: ANGLE AT TOP PERF: 36 @ 4764' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 7420' 1--17" MARKER JT W/ RA TAG 4 -5/8" 5 4764 - 4794 0 05/30/02 4 -5/8" 5 4844 - 4880 0 05/30/02 4 -5/8" 5 4894 - 4910 0 05/30/02 I 4 -5/8" 5 4962 - 4985 0 05/30/02 4 -5/8" 5 5024 - 5065 0 05/30/02 I 4 -5/8" 5 5096 - 5108 0 05/30/02 2 -1/2" 7484 - 7514 0 07/16/02 2 -1/2" 7524 - 7554 0 07/16/02 PBTD H 7723' .fft.ffi•f 7" CSG, 26 #, L -80, BTC-MOD, ID = 6.276" H 7808 DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 06/17/02 DAC/KK ORIGINAL COMPLETION WELL: L -109 12/30/02 DAC/KK GLV CORRECTIONS PERMIT No: 2012010 03/09/03 DRS/TP TVD CORRECTION AR No: 50- 029 - 23046 -00 03/19/03 BWS /TLH ADD PERFS FROM 7/2002 SEC 34, T12N, R11 E, 2376' NSL & 3728' WEL 04/08/03 DRS /TP TVD/MD CORRECTIONS 02/15/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~~A"~km+.t ~~~ ~~ ( ~'~ ~Li4'v:~ s~G.a~ f~iGi~w' ~. , .~~ d:' August 14, 2009 . bp ~~~~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, 0 C T 0 5 2009 ~iask~ ~ii Sc Gas Cons. Commi~~ior~ Anchorage ~~--~~1 ~1.s ~ ~ ~'~ . _r Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • ~ BP Exploretion (Alaska ) Inc. Surface Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10~04) Date L pad 8/13/2009 Well Name PTD # API # I~itial to of cement Vol. of cement um ed Final top of cement Cement top off date Cortosion inhibftor Corrosion i~hibitoN sealant date ft bbis ft na al L-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 62 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L•102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 102 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 5002923055A000 NA 2.75 NA 28.05 5/6/2009 ~-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 3162 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 5~29231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2071400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 225 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 2.2 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 325 NA 31.4 5/5/2009 L-271 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late blockin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surtace NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 162 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 ~ MEMORANDUM 'ro: Jim Regg %~ P.I. Supervisor ~ ~q -~~~~ ~~~ ~ FROM: LOU GT'irilaldl Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 31, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-109 PRUDHOE BAY UN BORE L-109 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: pRUDHOE BAY iJN BORE L-109 API Well Number: 50-029-23046-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG090726151306 permit Number: 201-201-0 Inspection Date: ~~26/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wejj L-]09 Ty ~ W T~ ' 4144 ~ jA ~ 420 4000 3860 3800 r~~~ P.T.D Zotzo~o TypeTest SPT Test psi aooo ~ I pA a9o soo sio soo ' Interval oT~R p/F P '~ Tubing~ 19so i9so~ ~900 ~900 ~ Notes• Pre MI swap MIT. 2.2 Bbl's pumped, 200 psi non-linear loss. Good test. J•~l,i n ~ -1~~~- ~sS~c~ ) ~c~~s; t,~:., y ,.~.,;' ;1(IC'~{' .~ w. r 3., ~w :, ns4iW i ` - ••, (?'"~ Friday, July 31, 2009 Page 1 of I e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor o l\et11( ~<t( oS' DATE: Wednesday, July 27, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORA nON (ALASKA) INC L-l09 PRUDHOE BAY UN BORE L-I09 :).@i~,.;};f?l \ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ....."..-:J "',.è P.I. Suprv" t~- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN BORE L-I09 API Well Number: 50-029-23046-00-00 Insp Num: mitCS050724093510 Permit Number: 201-201-0 Rei Insp N um: Inspector Name: Chuck Scheve Inspection Date: 7/23/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-I09 IType Inj. I N TVD 4144 I IA 490 4000 3950 I 3930 P.T. 2012010 TypeTest SPT Test psi 1036 lOA 340 350 350 350 Interval OTHER P/F P Tubing 750 875 850 800 Notes: Test performed prior to MI injection. , ",'~" ,'" G p q '¿OO;,I SCJ\NNE[J AU J ,J <. . Wednesday, July 27,2005 Page 1 of 1 ) ) ~~~~! :,} ~l~~:«~ / AItASIiA ORAND GAS / CONSERVATION COMMISSION a()þ-,~€:J,I FRANK H. MURKOWSK/, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bruce Smith Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay L-l 09 Sundry Number: 304-407 Dear Mr. Smith: 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 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. ( iiGe ~ ¡y, , (" ~ ~~Â A.N~~' Chairman ./ BY ORDER OF THE COMMISSION DATED this£day of November, 2004 SCANNED NOV 1 6 2.004l Enc!. ~Fr~Ë~'!Jr~ ALASKA ~IL AND ~~ST~g~S~~;~ON COMJISSION ~'¿?~~ APPLICATION FOR SUNDRY APPROVA.L !I' .t:, j ~.~ ~~~ ;:I~ i,~!¡ 20 AAC 25.280 Conductor 80 Production 7783 Surface 2693 Perforation Depth MD (ft): 7484 - 7514 7524 - 7554 Packers and SSSV Type: 4-1/2" Baker Premier Packer 4-1/2" Baker 8-3 Perm Packer 12. Attachments: Description Summary of Proposal D 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 6659.97 6687.7 6696.89 6724.6 1. Type of Request: Abandon D Alter Casing D 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): 76.40 KB 8. Property Designation: ADL-0028241 11. Total Depth MD (ft): 7820 Casing Total Depth TVD (ft): 6970.2 Length Detailed Operations Program D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: PerforateD WaiverD Annular DisposalD StimulateD Time ExtensionD OtherŒ] Re-enter Suspended Well 0 Convert to WAG Inj 5. Permit to Drill Number: 201-2010 /' 6. API Number /' 50-029-23046-00-00 Suspend D RepairWell D Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development D Exploratory D StratigraphicD Service Œ] ~/ 9. Well Name and Number: L-109 /" 10. Field/Pool(s): Prudhoe Bay Field I Borealis Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 7723 6804.0 MD TVD Size top 29 25 27 bottom top 109 7808 2720 Tubing Size: 3.5 " 9.3 # 4.5 12.6 # Packers and SSSV MD (ft): bottom 109.0 6959.1 2589.1 Tubing Grade: L-80 L-80 29.0 25.0 27.0 BOP Sketch D 13. Well Class after proposed work: ExploratoryD DevelopmentD Plugs (md): Junk (md): None None Burst Collapse 1490 7240 5750 Tubing MD (ft): 4653 23 470 5410 3090 7331 4653 4596 7273 Service ŒJ November 16, 2004 Date: 15. Well Status after proposed work: Oil D GasO PluggedO AbandonedO WAG ŒJ GINJD WINJD WDSPLD Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Bruce Smith f 1 J~ W Contact L~ Title Phone Petroleum Engineer 564-5093 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Approved by: Other: Subsequent For. BOP TestO Mechanciallntegrity Test D Location Clearance 0 Bruce Smith 11/2104 Sundry Number: a~l{-((b7 cL~y IP~ þáti (t-ruÇ. ~l,. BY ORDER OF THE COMMISSION Date: "--- SCANNED Nn" 1 ~ 20CM ORIGINAL RBDMS BFL NOV 1 6 2004 Form 10-403 Revised 06/2004 Ii's?>' SUBMIT IN DUPLICATE .z" ) TREE ~ 4-1/1 f)' 5M em WELLHEAD = 11" FI'vC 5M ACTlVÜOR ;; ............................ "'Nï A' 'KB. ä:ï~v ;........- .., 76.4ï' BF:- ELEJ''';'' .. ''''53jf KeF';'" ...-_............. 4õ"õ: "'~",.. _u... .,.",,,,,,,,,~,"~~L ....""^" .--"''''''.''''.''".''.'.. ._...~...~."...~.....". ..~.~..~~.~!~_..=:=...........~.~....(~L~?..~~:, Datum MD = 7502' Datum TVD = 6600' SS 19-5/8" CSG, 40#, L-80, ID = 8.75" H 2720' ~ Minimum ID = 2.813" @ 7260' 3-1/2" HES X NIPPLE 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 4653' 13-1/2"TBG, 9.3#, L-80, .0087 bpf,lD =2.992" H 7331' PERFORA llON SUV1Iv1A.RY RB= LOG: ANGLEA TTOPPffiF: 36 @ 4764' Note: Refer to Production œ for historical perf data SIZE SFF INTffiVAL Opn/Sqz DATE 4-518" 5 4764 - 4794 0 05/30/02 4:518" 5 4844 - 4880 0 05/30/02 4-518" 5 4894 - 4910 0 05/30/02 4-518" 5 4962 - 4985 0 05/30/02 4-518" 5 5024 - 5065 0 05/30/02 4-518" 5 5096 - 5108 0 05/30/02 2-112" 7484- 7514 0 07/16/02 2-112" 7524-7554 0 07/16/02 PB1D H 7723' 17" CSG, 26#, L-80, BTG-MOD, ID = 6.276" H 7808' ) L-1 09 I SAFETY NOTES: = =i 101T H9-5/8"TAMRJRTCOLLAR I I . 2261' H4-1/2"HESXLANDNGNIP,ID=3.813" ~ L ST MD 5 3803 4 4415 3 4520 GAS LIFT MANDRELS TVD DBI TY PE VL V LATCH 3495 34 KBG-2 DMY BK-5 3998 36 KBG-2 DMY BK-5 4082 36 KBG-2 DMY BK-5 WA Tffi R.OOD MANDRELS TVD DBI TYPE VLV LATCH 4223 37 MrvIG-W DMY RK 4270 37 MrvIG-W DMY RK RJRT DATE 0 06/17/02 0 06/17/02 RJRT DATE 0 09/07/02 0 06/17/02 0 09/07/02 ST MD 2 4694 1 4753 I I 4585' H4-1/2" HES X NIP, ID = 3.813" I ~ ~--t 4596' H7" X 4-1/2" BKR ffiEMER PKR, ID = 3.870" I , ,. I 4653' H4-1/2" X 3-1/2" XO, ID = 2.992" I =r B =r I I I 7260' H3-1/2" HES X NIP, ID = 2.813" I Z Z--I 7273' 1-17" X 4-1/2" BKR 5-3 A<R, ID = 2.992" I ~ t I 7298' H3-112" HES X NIP, ID = 2.813" I I 7319' H3-112" HESX NIP, ID =2.813" 1 I 7331' H3-112" WLEG, ID = 2.905" I r 7420' HT' Iv1A.RKERJTW/ RA TAG 1 I SCANNED NOV 1 6 2004 - DATE REV BY DA lE REV BY COMtvENTS 06117/02 DAaKK ORlGNAL COMR...EllON 12/30/02 DAaKK GLV CORRtCTIONS 03109/03 DRSlTP TVD CORRECTION 03119/03 BWSffLH A 00 ÆRFS FROM 7/2002 04108103 DRSlTP TVD/rvD CORRtCTIONS CO Mv1ENfS BOREALIS UNT WELL: L-109 ÆRMT f\b: 2012010 API f\b: 50-029-23046-00 SEC34, T12N, R11 E, 2376' NSL & 3728' WEL 8P EXploration (Alaska) Permit to Drill 2012010 MD 7820 ~TVD 6970 -- - --______0______----- - -- --..- REQUIRED INFORMATION ---- --~------ -- - - ------. ---- DATA INFORMATION I ì ) ~~ ~~~ ''\ DATA SUBMITTAL CÓMPLIANCE REPORT 7/6/2004 Well Name/No. PRUDHOE BAY UN BORE L-109 Operator BP EXPLORATION (ALASKA) INC 5/lCA¿ )Ò 1/1.) ~~ API No. 50-029-23046-00-00 .-//C" omplet"'on Status 1-01L Completion Date 6/17/2002 Mud Log No Samples No Types Electric or Other Logs Run: Well Log Information: Logl Electr Data Digital Dataset cTy~ - ~~~~~- Num~er Name ~ D Directional Survey Log Log Run Interval Scale Media No Start Stop 1 0 7820 25 Blu 1-3 298 7820 25 Blu 108 1364 25 Blu 1,2 ~. 7805 25 Blu 1,2 900 7805 .1: .4159. Gamma.Ray Induction/Resistivity See Notes ;CLø9 See Notes ~~ Ltôg" J~" iED C Sonic ur5ensity 5 Col 25 Blu 1,2 25 Blu 25 Blu 1,2 25 Blu 1,2 Directional Survey 06972 See Notes Aectional Survey See Notes Gamma Ray Cement Evaluation L--préssure ~.. ~g/ \1.09 I ~/ ¡ I 1/ ~pt \J{Og LÞ6g 7 : Log ~ .JIreÍJtron See Notes See Notes - --~---_._- ----~ 2 Blu 25 Blu 1-3 5 Col Blu 2700 7709 108 1332 0 7820 30 7802 ~ 1332 900 7805 900 7805 0 7820 <.100.- 1364 298 7820 2990 5625 ~ 7610 Current Status 1WINJ ~ Directional Survey No (data taken from Logs Portion of Master Well Data Maint) OHI CH Received Comments Open 6/14/2002 Case 7/26/2002 . / Open 6/21/2002 Open 8/9/2002 +-Platform Express with AIT and BHC sonic, Induction Presentation Open 8/9/2002 [ßtatform Express with AIT and BHC sonic, Triple combo Presentation SSTVD Open 8/20/2002 Open 6/21/2002 J?jatform Express Open 6/14/2002 Open 8/9/2002 lQPen Hole LDWG formatted edit .- Open 6/21/2002 cBlatform Express Open 8/9/2002 ¿BIatrorm Express Triple Combo Open 8/9/2002 ~orm Express with AIT and BHC sonic, Sonic Presentation Open 6/14/2002 Geodetic Open 6/21/2002 ~orm Express Case 7/26/2002 Case 8/16/2002 Case 8/9/2002 DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 ~g W;g J-log Permit to Drill 2012010 Well Name/No. PRUDHOE BAY UN BORE L-109 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23046-00-00 MD / 7820 ND 6970 Completion Date 6/17/2002 Completion Status 1-01L Current Status 1WINJ UIC Y :~- --- - ------ ---- i Log ~85 vS'onic 25 Blu 108 t--f348 Open 6/21/2002 ,rED C Gamma Ray 1-3 298 7820 Case 7/26/2002 ~g cSe€Notes. 25 Blu 1,2 900 7805 Open 8/9/2002 <Pffrtform Express with AIT and BHC sonic, Porosity Presentation ------- Log Sonic 5 Col 2990 7714 Case 8/16/2002 ED C 0'0936 See. Notes 50 1372 Open 6/21/2002 ---PEX AIT BHC data & See Notes 25 Blu 1,2 900 7805 Open 8/9/2002 ¿ßlatform Express with AIT and BHC sonic, Cement .---- and Hole Presentation 5 Col 2990 7500 Case 8/16/2002 25 Blu cJ.G8" 1364 Open 6/21/2002 ¿ßIátform Express Triple Combo 2 Blu .-¡os- 1332 Open 6/21/2002 Platform Express Sonic See Notes Caliper log -.. - --_._--~ Well Cores/Samples Information: , _.~-- Start --1995 Interval Stop 1 '4009- Sent Received Sample Set Number Comments Name etJttin!,G -tð4-S--~ -------. -------------- ADDITIONAL INFORMATION G Daily History Received? d)N b/N Well Cored? Chips Received? --v--f-.N-- Formation Tops Analysis Received? -YJ-N- - .~ ------ .--------- ---------~ --- --------~ Comments: -----~- ..- --------- ~ Date: Å~ ÂJ¡~ v\ --"-". ----- --------- Compliance Reviewed By: - ) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: SCHMOO-BE-GONE 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - 2903' FNL,3728'FEL,Sec.34,T12N,R11E, UM At top of productive interval 741' FNL,3754' FEL,Sec.03,T11N, R11E, UM At effective depth 835'FNL,3759'FEL,Sec.03,T11N, R11E,UM At total depth 867' FNL, 3761' FEL, Sec. 03, T11 N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Stimulate _X Alter casing - 5. Type of Well: Plugging - Perforate - Repair well - Other - 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Development - Exploratory- Stratigraphic- Service_X Prudhoe Bay Unit , 8. Well number (asp's 583188, 59780~ L-109 ~~~ ,"'V' Permit number / approval number (asp's 583203, 5974981) . 201-201 10. API number (asp's 583199, 5974887) 50-029-23046-00 11. Field / Pool Prudhoe Bay Field.! .Bqreali~ PPOL. I . , : I" r ' \ '; I (asp's 583197,5974855) 7808 feet 6959 feet Plugs (measured) Effective depth: measured 7723 feet Junk (measured) true vertical 6880 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 260 sx Arctic Set (Approx 133' 133' Surface 2697' 9-5/8" 462 SX Arctic Set Lite, 2720' 2589' 240 sx Class 'G' Production 7785' 7" 579 sx Class 'G', 121 sx 7808' 6959' Arcxtic Set 1 Perforation depth: measured Open Perfs 7484'-7514', 7524'-7554', Perfs Behind Isolation Assembly 4764'-4794', Behind Isolation Assembly 4844'-4880',4894'-4910',4962'-4985', 5024'-5065', 5096'-5108'. true vertical Open Perfs 6660'-6688',6697'-6725', Perfs Behind Isolation Assembly 4279'-4303', Behind Isolation Assembly 4343'-4372',4384'-4397',4439'-4458', 4490'-4524', 4550'-4560'. Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 4653'. 3-1/2" 9.3# L-80 TBG @ 7331'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 4596' MD. 7" x 4-1/2" Baker S-3 Packer @ 7273' MD. 4-1/2" HES 'X' Landing Nipple @ 2261'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl 2579 Subsequent to operation 03/24/2003 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations - Oil- Gas- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. A~ ~ JL T;tle: Te<:hnb,IAssistan' DeWayne R Schnorr If l.= Prior to well operation 03/12/2003 Form 10-404 Rev 06/15/88 . CasinQ Pressure TubinQ Pressure 1430 2030 7276 16. Status of well classification as: Suspended - Service WATER Injector Date March 25. 2003 Prepared by DeWayne R. Schnorr 564-5174 RBDMS 8FL ORIGINAL SUB~'T~ OUPLlCATE ~ ) ) L-109 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/20/2003 SCMOO-B-GONE--SBG: SCMOO-B-GONE 03/21/2003 SCMOO-B-GONE--SBG: SCMOO-B-GONE 03/24/2003 TESTEVENT --- INJECTION PRESSURE, PSI: 2,030 TYPE: PW VOLUME: 7,276 BWPD. EVENT SUMMARY 03/20/03 PUMPED 5 BBLS METHANOL FOLLOWED BY 106 BBLS SBG. LET SOAK FOR 3 HOURS. JOB IN PROGRESS. 03/21/03 PUMPED 77 WATER FOR FLUSH. FREEZE PROTECT TUBING WITH 10 METHANOL. 03/24/03 TESTEVENT --- INJECTION PRESSURE, PSI: 2,030 TYPE: PW VOLUME: 7,276 BWPD. FLUIDS PUMPED BBLS 21 106 77 204 METHANOL SCHMOO-BE-GONE WATER TOTAL Page 1 ) ) Î STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Pre-Prod Converted to Water Inj 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - Stimulate - Alter casing - 5. Type of Well: Development - Exploratory- Stratigraphic- Service_X 2903' FNL, 3728' FEL, Sec. 34, T12N, R11 E, UM At top of productive interval 741'FNL,3754'FEL,Sec.03, T11N, R11E,UM At effective depth 835'FNL,3759'FEL,Sec.03,T11N, R11E,UM At total depth 867' FNL, 3761' FEL, Sec. 03, T11 N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical (asp's 583188,5978098) (asp's 583203, 5974981) (asp's 583199, 5974887) (asp's 583197,5974855) 7808 feet 6959 feet Plugs (measured) Plugging - Perforate - Repair well - Other _X 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number L -1 09 9. Permit number I approval number 201-201 1302-263 10. API number 50-029-23046-00 11. Field / Pool Prudhoe Bay Field 1 Borealis Pool Effective depth: measured 7723 feet Junk (measured) true vertical 6880 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 260 sx Arctic Set (Approx 133' 133' Surface 2697' 9-5/8" 462 SX Arctic Set Lite, 2720' 2589' 240 sx Class 'G' Production 7785' 7" 579 sx Class 'G', 121 sx 7808' 6959' Arctic Set 1 Perforation depth: measured Open Perfs 7484'-7514',7524'-7554', Perfs Behind Isolation Assembly 4764'-4794', Behind Isolation Assembly 4844'-4880', 4894'-4910', 4962'-4985', 5024'.5065', 5096'-5108'. true vertical Open Perfs 6660'-6688',6697'-6725', Perfs Behind Isolation Assembly 4279'-4303', Behind Isolation Assembly 4343'-4372',4384'-4397',4439'-4458', 4490'-4524', 4550'-4560'. Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 4653'. 3-1/2" 9.3# L-80 TBG @ 7331'. 7" x 4-1/2" BakR'€a~irV~ÐMD. NOV 0 6 2002 Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 4596' MD. 4-1/2" HES 'X' Landing Nipple @ 2261'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure ~m.gil& Gas Cons. Commis~inn 14. Representative Daily Average Production or Inie Anchorage Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation 10/15/2002 15. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations - Oil - Gas - 17. I hÃebY certify that the foregoing is true and correct to the best of my knowledge. ~,;i"~ .-Ø J~ Title, Technical Assistan. DeWayne R. Schnorr ~ e 16. Status of well classification as: r \- ! : , . Form 10-404 Rev 06/15/88 . 4549 1853 Suspended - Service WATER Injector Date October 21.2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE ~ 09/06/2002 09/07/2002 09/07/2002 09/07/2002 10/09/2002 10/17/2002 10/18/2002 10/19/2002 10/19/2002 10/20/2002 ) ) L-109 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS SL REPLACED ALL LGLV's WITH DGLV's. ANNCOMM NEW WELL POST: GAS LIFT--TO DUMMY VALVES; MIT-IA NEW WELL POST: MIT-IA STARTED WATER INJECTION ANN-COMM CUIC PROGRAM): AC-FLUID LEVEL ANN-COMM CUIC PROGRAM): AC-BLEED; AC-FLUID LEVEL TESTEVENT ANN-COMM CUIC PROGRAM): AC-MITIA ANN-COMM CUIC PROGRAM): AC-MONITOR EVENT SUMMARY 09/06/02 SL REPLACED ALL LGL ViS WITH DGL Vis. 09/07/02 ANNCOMM ---MIT-IA PASSED TO 2500 PSI. LOST 75 PSI IN FIRST 15 MINUTES AND 35 PSI IN SECOND 15 MINUTES. 09/07/02 SET DGLV IN # 3 GLM. FINISHED LOAD AND TEST IA 2500#, LOST 75# IN 15 MIN, 35 MORE IN 30MIN ( GOOD TEST) BLEED IA TO 500# PULL EMPTY C- SUB. «< WELL SHUT-IN »> 10/09/02 STARTED WATER INJECTION --- PRODUCED WATER. 10/17/02 ANNCOMM --- T/I/O= 1600/1320/160 ( FOR STATE Mlrs) IA FL @ SURFACE. 10/18/02 AOGCC MITIA) IA FL @ SURFACE. GASSY FLUID. BLED IA FROM 1550 PSI TO 10/19/02 TESTEVENT --- INJECTION PRESSURE, PSI: 1,921 TYPE: PW VOL: 4,804 BPD. 10/19/02 MITIA PASSED TO 1720 PSI. (WITNESSED BY CHUCK SCHEVE OF AOGCC). PRESSURED UP ON IA FROM AN INITIAL 590 PSI TO 1720 PSI. START TEST. AFTER 15 MINUTES THE IA PRESSURE WAS AT 1660 PSI AND AFTER 30 MINUTES THE PRESSURE WAS AT 1690 PSI. 10/20/2002 ANNCOMM --- T/I/O/= 1510/690/140 MONITOR WHpls. POST MITIA. BBLS 0.8 71 71.8 FLUIDS PUMPED 60/40 METHANOL WATER. DIESEL TOTAL Page 1 ') MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy 0 Taylor ~ Chairman ~ DATE: October 19, 2002 THRU: Tom Maunder P.I. Supervisor SUBJECT: Mechanical Integrity Tests BPX L Pad L-109 & L-119 PBU FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well L-109 Type Inj. S TV.D. 4596 Tubing 1750 1580 1700 1750 Interval I P.T.D. 201-201 Type test P Test psi 1149 Casing 590 1720 1660 1690 P/F e Notes: New Well Well L-119 Type Inj. S T.V.D. 66447 Tubing 1700 1700 1700 1700 Interval I P.T.D. 202-064 Type test P Test psi 16612 Casing 1100 1850 1850 1850 P/F e Notes: New Well Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year CYCle s = SALTWATER 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 0= Other (describe in notes) Test's Details I traveled to BPXs L Pad and witnessed the initial MIT on wells L-I09 and L-119. The pretest tubing and casing pressures were observed and found to be stable. The casing was then pressured up and observed for 30 minutes with the well demonstrating. good mechanical integrity. '\ ""Ìc::.\""~ \' ~"""<;. '-2>~ Q e, '" '- - \~ "-:I C). So '-IG.~ ~\fu: ~~" \. \- ~ ~<;. -\ . ~o ,-a'1¡---"~ '-J~\ '"-ti\\c~ '\\1'-..~\' ~O-~~ M.I.T.'s performed: ~ Attachments: Number of Failures: Q Total Time during tests: 2 hour cc: M IT report form 5/12/00 L.G. MIT PBU L 10-19-02 CS.xls 10/25/2002 Schlum~el'gel' Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth /-- Well L-105 d()d.-O 5'l L-109 ð-oJ..ao i L-108 ó1Q;i- 109 L-108 r L-108 J¡ f~~- Job# Log Description 22343 CET/USIT 22341 USIT 22315 OH MWD GR 22315 MD VISION GR 22315 TVD VISION GR Date 07/16/02 06/14/02 06/27/02 06/27/02 06/27/02 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 AK 99508-4254 Date Delivered: RECEIVED AUG 20 2002 Alma OH & Gas Coos. Commission Anchorage NO. 2324 8/16/2002 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Color Sepia 2 2 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TIN: Beth Receiv~7~~J Å BL CD 1 Cbor~ bp ) ) ... ,\t'."'. ~~~ ~~. .-,...- -~.-.. ""'I~ ~....-.- .'I'.~I\" ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 20, 2002 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for L-1 09 Conversion from Pre-Produced Injector to WAG Injector BP Exploration Alaska, Inc. proposes to convert well L-109 from a pre-produced / injection well to an active injector (both water and MI (WAG flood)) as part of the Borealis Pool Flood Development project. The procedure includes the following major steps: S DfT, Dummy off GL Design, Run Static Survey. MITIA to 4000 psig. / Stim Pump HPBD Slickline Work: 1. Drift and tag to at least 7560' MD, to verify access to perfs. 2. DGLVs 3. Obtain SBHPS stop counts at: 7610' - 40-min, 7501' - 20/30min, 7393' - 20min. MITIA to 4000 psig. Last test: Max Deviation: Perf deviation: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S value: Wellbore Fluids: BHT & BHP: Reference Log: / 7/22/02 500 BOPD 36.8° @ 4672' MD 22.3° @ 7474' MD 2.813"X nipple @ 7260 & 7298" MD Static 7/17/02 Static 7/17/02 0 ppm 4/9/02. Freeze protected tubing & IA to 3200' with diesel. L-109i 158.8°F & 2825 psia @ 6600' TVDSS / Schlumberger PEX 6/6/02 LonQ Term Operational Plan / L-109 was pre-produced for 8 days. This pre-production has shown benefit in cleaning up wellbore damage. The well was tie-into gas lift service and production header facilities temporally. The pre-production cleanup period is completed; the well has been swapped to injection service. L-109 is designed ~6* ~ APPLICATION FOR SUNDRY APPROVALS ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ') l 'i/¿I/O'l- 9/~~ 8'/22- 1. Type of request: Abandon- Suspend- Conversion From Alter casing - Repair well- Prod to Inj'/ Change approved program- 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at suriace 2376' FSL, 1552' FWL, Sec. 34, T12N, R11 E, UM At top of productive interval 741' FNL, 3754' FEL, Sec. 3, T11N, R11W, UM At effective depth 834' FNL, 3760' FEL, Sec. 3, T11 N, R11W, UM At total depth 871' FNL, 1518' FWL, Sec. 3, T11 N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 110' 20" Suriace 2693' 9-5/8" Production 7808' 7" Perforation depth: 260 sx Arctic Set (Approx) 110' 462 sx Arctic Set Lite, 240 sx Class 'G' 579 sx Class 'G', 121 sx 7808' Arctic Set 1 Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development 1 Exploratory - Stratigraphic - Service- (asp's 583188, 5978098) (asp's 583202, 5974981) (asp's 583199, 5974887) (asp's 583197, 5974850) 7808 feet 6959 feet 7723 feet 6880 feet Plugs (measured) Junk (measured) Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - Other 1 ./ Cemented 6. Datum elevation (DF or KB feet) RKB 76.4 feet 7. Unit or Property name BOREALIS UNIT 8. Well number L -1 09 9. Permit number / approval number 201-201 10. API number 50-029-23046-00 11. Field / Pool PRUDHOE BAY FIELD/BOREALIS POOL Measured Depth True vertical Depth 110' 2720' 2589.1' 6959.1' measured Open: 74841 - 75141, 75241 - 7554' Behind Dummy Waterflood Valves: 4764' - 47941,48441 - 48801,48941 - 4910' 4962' - 49851,50241 - 5065', 5096' - 51081 true vertical Open: 6660' - 6687.7', 6696.9' - 6724.6' Behind Dummy Waterflood Valves: 4278.7' - 4302.81,4343.1' - 4372.21,4383.61 - 4396.6' 44391 - 4457.91,4490' - 4524.11,4550' - 4560' ~''''' I)"~ 4-1/2",12.6 #, L-80 at 4653' MD, 3-1/2", 9.3 #, L-80 at 7331' MD fe. F.' [¡ ir' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 2- 7" X 4-1/2" Bkr Premier Pkrs at 4596' and 7273' MD l\UG ~~ C 200;? 13. Attachments Description summary of proposal _X 14. Estimated date for commencing operation Week of 8/19/02 16. If pro~osal was verbally approved \¡J. Au.6.a-r T Name of approver 17. I hereby certify that the foregoing is true and corre ~ --J Signed Bruce Smith Detailed operations program - 15. Status of well classification as: Alaska ffiAfi' @.~~tffij4S, (,cnl¡nHssion ..~nchoraQe Oil-1 16 I z.., J",z... D~te approved Service to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - ~9P Test - Location clearance - l ¡ I i Mechanical Integrity Test ..þ. Subsequent form required 10- TO I .1t-cj.~..(.A:/ ~ G(..epr17~~al ~ned~~pa'¥LL¿¿ "",c'l . Approved by order of the Commission Cammy Qechsli TaylOf Commissioner Form 10-403 Rev 06/15/88 . Title: Petroleum Engineer Oh»f('~~~fAL ,""\. f, lr~'iì ¡ ~ \.Ii /.~~ ï .,l i \¡j è \ Gas- Suspended - Date 8/19/02 Prepared by Garry Catron 564-4657 I Approval no. 2 J Z 3D -2.100 Date ~/~ SUBMIT IN TRIPLICATE to support proc. ')rs L-11 0, L-100 and to a lesser dl}e L-114. A second injector is present in the same block to provide additional support, well L-111. This well is designed as a dual injector, with the upper zone in the Schrader Bluff currently isolated. The well is planned to be used for Kuparuk service only. Once the Orion Field has approved PA, Tract Operations and/or Pool Rules, dual injection maybe requested for this wellbore. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5093, hm: 345-2948, cell: 440-8008 or e-mail me at SmithBW@BP,com Sincerely, ~~~.ì '-'"' Bruce W. Smith GPB Borealis Development Engineer ) TREEt'= 4-1/16" 5M CIW WS.Ll-EAD = 11" FMC5M ÄCfUATöR'=" .. N'À KB. ELE\i;"76.4: SF. ELEV = 53.6; KÓP='"'''' . . 400' Max Angle = . 36 @i""4298' .m ....'" ...,"'''' . Datum MD = " ..' .. Datum TV D= 8800' SS 19-5/8" CSG, 40#, L-80,ID = 8.75" H 2720' ~ Minimum D = 2.813" @ 7260' 3-1/2" HES X NIPPLE 14-1/2" TBG, 12.6#. L-80, .0152 bpf, 10 = 3.958" H 4653' 13-1/2" TBG, 9.3#, L-80, .0087 bpf, 10 = 2.992" H 7331' PERFORATION SUMMA. RY REF LOG: ANGLE AT TOP PERF: 36@4764' Note: Refer to Production œ for historical perf data SIZE SFF INlERVAL Opn/Sqz DATE 4-518" 5 4764 - 4794 0 05130102 4-518" 5 4844 - 4880 0 05130102 4-518" 5 4894 - 4910 0 05130102 4-518" 5 4962 - 4985 0 05130102 4-518" 5 5024 - 5065 0 05130102 4-518" 5 5096 - 5108 0 05130102 PBID H 7723' 17" CSG, 26#, L-BO. BTC-Moo, 10 = 6.276" H 7808' ) L-1 09 I SAFErY NOTES: = =i 1017 H9-5/8"TAM RJRf COLLAR I I . 2261' H4-1/2" HES X LANDNG NIP, ID = 3.813" ~ L ST MD 5 3803 4 4415 3 4520 GAS LIFT MANDRELS TVD DEV 1YPE VLV LATCH 3495 34 KBG-2 DMY BK-5 3998 36 KBG-2 DMY BK-5 4082 36 KBG-2 RP BK-5 WATER FLOOD fv\<\NDRELS TVD DEV 1YPE VLV LATCH 4223 37 MM3-W DMY RK 4270 37 MM3-W DMY RK PORT DA 1£ 0 06117/02 0 06117/02 PORT DA 1£ 0 06117/02 0 06117/02 06117/02 ST MD 2 4694 1 4753 I . 4585' H4-1/2" HES X NIP, ID = 3.813" I ~ ~~ 4596' H 7" X 4-1/2" BKR FREMER PKR, ID = 3.870" I \, I 4653' H4-1/2" X 3-1/2" XO, D = 2.992" I ~B . . I 7260' H3-1f2"I-ESXNIP,ID=2.813" I Z ~~ 7273' H7' X 4-1/2" BKR 8-3 A<R.ID = 2.992" I ~ ~ I 7298' K3-1/2" HES X NIP, 10 = 2.813" I I 7319' H3-1f2" I-ESX NlP,ID =2.813" I I 7331' H3-1f2"WLB3,ID=2.905" I e---t 7420' H7" MARKER JT WI RA TAG I - DATE REV BY COMM::NTS 06/17102 C\A. C'KK ORIGINAL COMR..ETION DATE REV BY COrvtAENTS PRUŒiOE SAY UNIT WELL: L-109 PERMT t-b: 2012010 API t-b: 5O-02~23046-00 SEC 34, T12N. R11 E. 2376' NSL & 3728' WEL BP Exploration (Alaska) ) MECHANICAL INTEGRITY REl'ORT . .......... :. I G R E L E;. S :::: - OPER & FIELD gp'. B.ot{?tclt' ç "WELL NUMBER L -101. ~?UD DA'!E:: ~n: ~LL DATA TD: 1-f () if Jill.. ~?}t~/7P TVD; ? 13 TD : -¡ 7 1.""5 HI? & f -f 0 TVD Cë.si~g: -, // ¡ Shoe: 71jo-f' HD (ç;JrS(1 TVD i DV: S'f..l¿(") MD .T'Vu ~:":Je::-: Shoe: HD TVD; :OF; HI) :"'rD :'wbi:-:g: (1 " 4- ¡¿ Packer 7 ~1;, t . HD TVD í Set a.t I '7"~ "7-" L ;., . ".J ::.ole Size B".~/rf.: I' anå P e-r- f ~ 7(../"-~ -~ ',0 - --1 ¡,- ('- ,,' I ~ 0 ¡ ...). ':-,) '-( ~CHþj.rIC;.L INTEGRITY - PART /1 Annulus Press Test: ~p 15 min 3 0 min Cowme~t.s: All I' YrJ'f,';., .f' ,,;" !;". 4 '" t, "'.> rl \.~«¡"" '; I ."t" ;,j U ,...- HE CHÞ_1\TI CAL INTEGRITY - PART 42 Cement Volumes:' Þ-..mt. Liner ; Csg:; ¿. r 1l~1 it.,f2 ðJ,.,../ (;( l'r~~1 { ,.' d fj(, . 'I., ' i' ,. -+ .' / q D% 1;k: C~t ~ol to cover per=s 1 '< -~". (/t.. t, ''''Î C:ð \f..€.",v. '-l\~.o ¡). I;,;.l.r:;~" J~ ..~:" ~ -t '," ,,( ''', t.~ t'~rO ( ')) .' "1111'° \...,ljI'! '''''' \. Theoretical Toe $CÆV"~~ - Cement Bond Log (Yes or No) ,tj ; In AOGCC File' v CBL ~valuationf =one ëDove perfs ,"",. l ) , '... .. J Y'~ f ".'" ~ .... r ;~\ ," l:~~, ('.I.' .".,1 S, :i" M ...¿:.: ,. ..: /'-'1 / i> '." I ~... ). Production Log: Type Jl0.Jllt ~ ¡/ k. /': 0!~. t;,,-,... ~ ~ !/ ::: I r, . S(~ ,.,.t~. l/~,'/ rot . ~ '" 'f. f - ¡ ,.1 It'" '.1 .' i..,' ;".... (J....,/ -...- '''''J'''L~ . ! f.~ I! n'. .r. .. ",,1":1 /' ,.} . .,"1 :\1..::.':'<<::\ ,,~! I r( J ¿ --..'-~~"-'- , Evaluation , ' . i ¡ ¡ CONC~LUSIONS : ...!..,.:" I :' ? ar t: f 1: I/' r T' y-,C:. / .'.' ¡;""~ d' r ;. ,,).. - .~/ f ' .¿.<- .;...../ ,è'-- J I ¡'. ?ar:: : Z :4~ (,(..b b I{ ~ p) yt.-( (~ b ~ J¡", I 111. d)Cr, -{" 1 /\.'1/ y? j .\.1 \! ",.( 'W.,,{..AJ'~'!, I, l;.t ,"~.. ( d/ ¡ I \I-l6Â -. -{¡¿I/O L ' . Schlumbepger NO. 2313 8/15/2002 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis , - Well Job# Log Description Date Color Sepia L-105dni~05 '){ 22342 CET/USIT 07/15/02 2 L-1 05 22344 US IT 07/19/02 2 L-109 ~()/-rl(") J 22340 US IT (2) & SCMT 07/9&10/02 6 ~ L-108 ~Od."1()9 22314 OH PEXlAIT/BHC 06/27/02 L-1 09 ' 22314 PEX-AIT 06/27/02 ~-læ L-110 22314 BHC 06/27/02 L-111 22314 PEX-NEUTRONIDENSITY 06/27/02 LDf L-112 22314 PEX-QUAD COMBO 06/27/02 L-113 22314 PEX-SSTVD 06/27/02 L-114 V 22314 PEX-HCAL 06/27/02 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 AK 99508-4254 RECE\VED AUG 1 6 2002 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATIN: Beth Date Delivered: Alaska O~ & Gas Con>. C.ommission Anchorage Received by: BL CD 1 1 1 1 1 1 ) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Ia Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Locati~n of well a~ surface ~OMiCË'~ÓN \ .~Q1 2376 NSL, 3728 WEL, SEC. 34, T12N, R11 E, UM, . OAl~:. ,J " ~. ' . ,,', At top of productive interval , I, I', '(;>71'~ ,,'" r 557' NSL, 3628' WEL, SEC. 34, T12N, R11 E, UM 1...t?V:¿H\ .W:;. ì 1,'~,'. '. ", i.. '. .""" '. . ~ At total depth ~ V - , ~ ß. ,.. ":' .'" ,..~ 4408' NSL, 3762' WEL, SEC. 03, T11 N, R11 E, UM t,,.. -~.~--..;....,..::.J --..~"......- 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. RKB = 76.4' ADL 028241 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 5-30-2002 6-5-2002 6-17-2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 7820 6970 FT 7723 6880 FT III Yes 0 No 22. Type Electric or Other Logs Run RES 1 AIT, DT I BHC, CNL, LDL, GR, Caliper, SP, MRES, MWD , SONIC, GYRO, CBL , CBT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 91.5# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 27' 2720' 12-1/4" 462 sx Arcticset Lite, 240 sx 'G' 7" 26# L-80 25' 7808' 8-3/4" 579 sx Class 'G', 121 sx Arctic Set 1 Classification of Service Well Pre-Produced Injector 7. Permit Number 201-201 8. API Number 50- 029-23046-00 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number L.109i 11. Field and Pool Prudhoe Bay Field 1 Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2261' MD 1900' (Approx.) TUBING RECORD SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 4653' 3-1/2",9.2#, L-80 4653' - 7331' 26. ACID, FRACTURE, CEMENT SQUEezE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2420' Freeze Protected with 85 Bbls of Diesel 24, Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-5/8" Gun Diameter, 5 SPF 2-1/2" Gun Diameter, 6 SPF MD TVD MD TVD 25. 4764' - 4794' 4844' - 4880' 4894' - 4910' 4962' - 4985' 5024' - 5065' 5096' - 5108' 4279' - 4303' 4343' - 4372' 4384' - 4397' 4439' - 4458' 4490' - 4524' 4550' - 4560' 6660' - 6688' 6697' - 6725' 7484' -7514' 7524' - 7554' 27. Date First Production July 23, 2002 Date of Test Hours Tested 7 -22-2002 4 Flow Tubing Casing Pressure Press. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR Oll-BBl TEST PERIOD 500 CALCULATED Oll-BBl 24-HoUR RATE GAs-McF 500 GAs-McF WATER-BBl 0 WATER-BBl AMOUNT PUllED PACKER SET (MD) 45961 7273' CHOKE SIZE GAS-Oil RATIO 1000 Oil GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit ~~~~ipS.'~ ; : -~. : ~.. I' . No core samples were taken. \ . ,~r:.o' 0,iJ3 '1 ,5 ~~GG;? (~ ì':' 0 R ¡ G ! ~!J A ~ U M 5 ~ L I\UG I 9 20fš'ubmit In Duplicate ¡llasi<a Od 3, (::8':; :~~(ln~ ~ .u:;~,~-d3~:}\Cii .. \,' , '.' "~'~"~'ho~,,;!;,.e ."./-\Hl.d ... a~ ~;. Form 10-407 Rev. 07-01-80 ) 29. Geologic Markers Marker Name Measured Depth Schrader Bluff N Sands 45751 Schrader Bluff 0 Sands 4764' Base of Schrader Bluff Top of Colville 5202' CM1 63731 Top of Kalubik 7319' Top of Kuparuk D 74561 Top of Kuparuk C4 7480' Top of Kuparuk C3 75021 Top of Kuparuk C2 7558' Top of Kuparuk C1 7617' Top of Kuparuk B 7674' ) 30. Formation Tests True Vertical Depth .. Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 4127' 4279' 4640' 5666' 6508' 6634' 6656' 6677' 6728' 6783' 6835' IS, 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Summary and a Leak-Off Test Integrity Summary. - . ' 32. I hereby certify that the foregoing is true and correct to the best of my knowledge . Signed Terne Hubble ~ J\f\i..( . ~ftle ~~hnical Assistant L-109i 201-201 Well Number Permit No. I Approval No. Date Cß-13 .O~ Prepared By Name/Number: Sondra Stewman, 564-4750 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification ot 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 only 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 28: If no cores taken, indicate 'nonel. ITEM 27: Method ot Operation: Flowing, Gas Lift, ROd Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 (~, \:,-"\ ~ ~ ~:, (I '1\ 11~. \ \.-'<'f..,~I' t ~ \ '~\ 1, :,:, ,\ '~ i \; L- Legal Name: L-109 Common Name: L-109 Test Date 6/3/2002 6/12/2002 LOT LOT Test Type Test Depth (TMD) 2,720.0 (ft) (ft) BPEXPLORATION Leak-Off Test.. Summary Test Depth (TV D) 2,602.0 (ft) (ft) AMW 9.30 (ppg) (ppg) SUrfacePressûre 705 (psi) (psi) Leak ()ff..Pres$ure (aHP) 1,962 (psi) (psi) 14.52 (ppg) 14.52 (ppg) ~ -" Printed: 6/24/2002 1: 18:09 PM ) ) BP EXPLORATION °pË!ratibns Summary Rèport Page 1of1 0 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L -1 09 L-109 DRILL +COMPLETE NABORS NABORS 9ES Start: Rig Release: Rig Number: 9-ES 5/29/2002 Spud Date: 5/30/2002 End: 6/17/2002 Date From- To Hours Task Code NPT Phase Description of Operations 5/29/2002 00:00 - 15:00 15.00 MOB P PRE Blow down all lines. Move camp to edge of pad. Pull pits away f/ sub & spot on L-Pad. Jack up & move sub away f/ V-1 02. Location extremely soft. Lay mats to access road. ove sub onto mats. ND double gates & annular. Lay derrick over. Juggle mats around to L-Pad. Move sub to L-Pad. 15:00 - 00:00 9.00 MOB P PRE Raise derrick & bridle down. Change out HCR valve. NU double gate, single gate, & Hydril. Secure to stump. Spot shop. Start RU floor. Lay mats & herculite. Spot sub on L-109. Lay mats for pit complex. 5/30/2002 00:00 - 02:00 2.00 MOB P PRE Spot and level substructure. Place BOP and wellhead in cellar since there will be no access after spotting pits. 02:00 - 03:00 1.00 MOB P PRE Spot pit complex. 03:00 - 04:30 1.50 DRILL P SURF Change out flow nipple and install riser. 04:30 - 09:30 5.00 DRILL P SURF Load pipe shed. Build spud mud. 09:30 - 10:00 0.50 DRILL P SURF Service top drive. 10:00 - 11 :00 1.00 DRILL N DPRB SURF PU 2 joints of HWDP tag ice in conductor at 33'. 11 :00 - 12:30 1.50 DRILL N DPRB SURF Circulate thru ice plug to 93'. 12:30 - 17:00 4.50 DRILL P SURF PU HWDP ,jars,collars, and drill pipe and stand back. 17:00 - 17:30 0.50 DRILL P SURF PU MWD and motor. 17:30 - 18:00 0.50 DRILL P SURF PJSM Pre Spud meeting. 18:00 - 18:30 0.50 DRILL P SURF RU Schlumberger and Gyro Data. 18:30 - 19:00 0.50 DRILL P SURF MU BHA#1 and tag ice at 40' 19:00 - 19:30 0.50 DRILL N DPRB SURF Drill ice plug 19:30 - 20:30 1.00 DRILL P SURF Continue to MU balance of BHA 20:30 - 23:30 3.00 DRILL P SURF MU collars. Continue to drill ice. Hit cement at 106'. Drill to 262'. 23:30 - 00:00 0.50 DRILL P SURF Run gyro survey. 5/31/2002 00:00 - 00:30 0.50 DRILL P SURF Directionally drilled to 354'.57 UP, 57 DN, 57 Rot 80 RPM TQ 1.6 00:30 - 01 :30 1.00 DRILL P SURF POH add drilling jars to BHA. 01 :30 - 02:00 0.50 DRILL P SURF Gyro survey. 02:00 - 15:30 13.50 DRILL P SURF Directionally drill to 1659', 86 up,81 dn, 82 rt Torq off bottom 2500 ft-Ibs Torq on bottom 4000 ft-Ibs. @ 2400 psi.Surveying every stand. 15:30 - 16:30 1.00 DRILL P SURF Circulat hole 250% and pump pill. 16:30 - 18:00 1.50 DRILL P SURF POH for bit. Minimum swabbing. 18:00 - 19:00 1.00 DRILL P SURF Change out bit and lay down UBHO. 19:00 - 19:30 0.50 DRILL P SURF Service top drive 19:30 - 21 :00 1.50 DRILL P SURF RIH to 975 hit obstruction. Push to 1565. 21 :00 - 00:00 3.00 DRILL P SURF Ream from 1565 to 1638. Obstruction stopped moving. Drilled it up to 1659 hard drilling. Continue to drill to 2121' 92 up,82dn, 85 rt,650 gpm @ 2400 psi Torq off bottom 2500 ft-Ibs Torq on bottom 4000 ft-Ibs. 6/1/2002 00:00 - 03:00 3.00 DRILL P SURF Directionally drill to 2735 TD. 03:00 - 04:00 1.00 DRILL P SURF Spot pill monitor well. 04:00 - 06:30 2.50 DRILL P SURF Wiper trip to HWDP @ 907'. Intermittent 30K over 1780' - 1670'. Wiped out OK. Last 2 stds pulled good. 06:30 - 08:00 1.50 DRILL P SURF RIH. Set down @ 1220'. Ream past. Pushed obstruction to bottom. 08:00 - 09:30 1.50 DRILL P SURF Wash last stand down. CBU. Quite a bit of solids on BU. Circ two La Vis sweeps. Hole clean. 09:30 - 13:30 4.00 DRILL P SURF POH. Pulled 25K over @ 1780'. Wiped out OK. Stand back HWDP & DC's. Hole looks good. LD motor & MWD. Clear floor. Printed: 6/24/2002 1: 18:25 PM Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: ) BP EXPLORATION Operations$ummary. Report L -1 09 L-109 DRILL +COMPLETE NABORS NABORS 9ES Start: Rig Release: Rig Number: 9-ES 5/29/2002 ) Page 2 of1 0 Spud Date: 5/30/2002 End: 6/17/2002 Date From- To Hours Task Code NPT Phase Descri ptionof Operations 6/1/2002 13:30 - 17:00 3.50 DRILL P SURF RU SWS. MU PEX / Sonic. RIH. Tagged up @ 1375'. Worked down to 1390'. Hole started getting sticky. Log out. LD tools. RD SWS. 17:00 - 19:30 2.50 CASE P SURF PU landing jt & make dummy run. RU to run 9 5/8" casing. PJSM. 19:30 - 00:00 4.50 CASE P SURF MU shoe jts. MU Frank's tool. Check floats-OK. Run 9 5/8" 40#. Tight @ 1750'. Work through to 1800'. Circ down to 1900'. 6/2/2002 00:00 - 00:30 0.50 CASE P SURF Continue to RIH with 9-5/8" 40# casing. MU torq 9000 ft-Ibs Had to work pipe down from 2200 to 2500' 00:30 - 01 :00 0.50 CASE P SURF PU landing joint and lay down Franks fill-up tool. 01 :00 - 03:00 2.00 CASE P SURF Circulate and condition mud. PU 146K SO 105K collar hanging up on conductor limit pipe movement to 1'. Circulate at 10 bpm 680 psi. 03:00 - 03: 15 0.25 CASE P SURF PJSM for cement job. 03:15 - 06:30 3.25 CASE P SURF Pumped cement as follows: 10 bbl chemical wash,75 bbl Mud Push,Bottom plug, 365 bbl of lead cement, 50 bbl tail cement, Top Plug, 10 bbl H2O. Displace with rig pump. Bump plug on calculated strokes with 1300 psi. Float held. Dye seen at 490 bbl. Surface to surface volume gauge hole = 438 bbl. Indicating 52 bbl of washout. Got back 90 bbl cement indicating that 87 bbl washout existed. Annular volume+ shoe track = 238+87bbl washout +90 bbl returns = 415 bbls pumped. 06:30 - 08:30 2.00 CASE P SURF Flush stack. RD cementing head, LD landing joint. 08:30 - 10:30 2.00 CASE P SURF ND riser 10:30 - 12:00 1.50 CASE N MISC SURF Level rig due to settling. 12:00 - 14:00 2.00 CASE P SURF ND Hydri divertor and position in cellar. Site location to tight to remove Hydril from cellar. 14:00 - 16:00 2.00 CASE P SURF NU FMC speed head. 16:00 - 21 :00 5.00 CASE P SURF NU BOP stack 21 :00 - 00:00 3.00 CASE P SURF Test BOP's 6/3/2002 00:00 - 01 :00 1.00 CASE P SURF Continue to test BOP. 01 :00 - 01 :30 0.50 DRILL P PROD1 Install wear ring. 01 :30 - 05:30 4.00 DRILL P PROD1 PU drill pipe and stand it back. 05:30 - 08:30 3.00 DRILL P PROD1 PU BHA #3. 08:30 - 09:30 1.00 DRILL P PROD1 RIH test casing to 1000 psi after bha passed TAM port collar. OK. 09:30 - 10:30 1.00 DRILL P PROD1 Cut drill line 10:30 - 11 :00 0.50 DRILL P PROD1 Service top drive. 11:00-12:00 1.00 DRILL P PROD1 Continue to single into hole to 2422' 12:00 -13:00 1.00 DRILL P PROD1 Test casing to 3500 psi for 30 min. OK. 13:00 - 13:30 0.50 DRILL P PROD1 RIH. Tag cement at 2610' F.C. @2639 13:30 - 15:30 2.00 DRILL P PROD1 Drill shoe track and 20' of new formation. 15:30 - 16:30 1.00 DRILL P PROD1 Circulate bottonms up and change over to new mud. 550 GPM @ 2200 psi. 50 RPM, TO off 2700 ft-Ibs, TO on 3600 ft-Ibs ,104 UP, 85 DN, 92 RT. 16:30 - 17:00 0.50 DRILL P PROD1 Perform L.OT. 14.5 ppg E.M.W. 17:00 - 23:30 6.50 DRILL P PROD1 Directionally drill to 3914' 121 UP, 97 DN, 108 RT, 2600psi @ 600 GPM,TO off = 3000 ft-Ibs, TO on = 4800 ft-Ibs, Sweeps HI-La every 200'. Ream every stand. 23:30 - 00:00 0.50 DRILL P PROD1 Circulate HI-LO sweep in preparation for short trip. 6/4/2002 00:00 - 00:15 0.25 DRILL P PROD1 Continue to circulate sweep. 00:15 - 02:30 2.25 DRILL P PROD1 Short trip to the shoe. Pulled the first 4 stands and back reamed the next 9 to the shoe. Circulate bottoms up.Sweeps Printed: 6/24/2002 1: 18:25 PM ) BP EXPLORATION Operations Summary Repol1 Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: Date 6/4/2002 6/5/2002 6/6/2002 6/7/2002 L-109 L-109 DRILL +COMPLETE NABORS NABORS 9ES 5/29/2002 Start: Rig Release: Rig Number: 9-ES ') Page 3 of to Spud Date: 5/30/2002 End: 6/17/2002 From - To Hours Task Code NPT Phase Description of Operations 00:15 - 02:30 2.25 DRILL P PROD1 are being very effective. 02:30 - 03:00 0.50 DRILL P PROD1 Service top drive. 03:00 - 03:30 0.50 DRILL P PROD1 RIH 03:30 - 14:00 10.50 DRILL P PROD1 Drill from 3914 to 5501137UP, 117 DN,128 RT, TO Off = 3200 ft-Ibs, TO on = 5200 ft-Ibs 600 GHM @ 3280 psi. 14:00 - 15:00 1.00 DRILL P PROD1 Pump Lo- Hi sweep @ drilling rate. Monitor well. Pump Dry job. 15:00 - 16:30 1.50 DRILL P PROD1 POH Wipe thru tight spots @ 4780- 4400' No swabbing. RIH to 5408'. No problems. 16:30 - 17:00 0.50 DRILL P PROD1 Ream from 5408' to 5501'. No fill. 17:00 - 00:00 7.00 DRILL P PROD1 Directionally drill to 6218'. 145 UP, 123 DN, 133 RT, 575 GPM @ 3500 psi TO On= 7000 ft-Ibs, TO Off = 4000 ft-Ibs. 00:00 - 01 :30 1.50 DRILL P PROD1 Continue to directionally drill to 6432. 01 :30 - 08:00 6.50 DRILL P PROD1 Begin bleeding in mud to weight up to 10.1 for the HRZ drilling. 6901' 162 up, 132 dn, 145 rt,3500 psi off, 3280 psi on bottom @ 584 gpm, TO on = 6500 ft-Ibs TO off= 3500 ft-Ibs. POB 10-18. Cal ECD = 10.56 ECD 10.93 AST = 2hr, ART = 4.7 hr. 08:00 - 09:30 1.50 DRILL P PROD1 Ciculate La-HI sweeps at 600 gpm UP and 485 GPM dn. @ 110 rpm. Monitor hole. Pump dry job. 09:30 - 11 :30 2.00 DRILL P PROD1 POH to shoe 172 up, 130 dn, Good Trip 11 :30 - 14:30 3.00 DRILL P PROD1 Change out pump liner per the programed pumping schedule.from 5.5" to 5". Service top drive 14:30 - 15:00 0.50 DRILL P PROD1 RIH to 3175'. Hit obstruction. 15:00 - 16:30 1.50 DRILL P PROD1 Break circ & wash down pushing obstruction to 3250'. 16:30 - 17:30 1.00 DRILL P PROD1 Continue to RIH dry to 6901' condition mud due to ECD and shaker overrun. 17:30 - 00:00 6.50 DRILL P PROD1 Directionally drill to 7557'. 169 up, 143dn, 158rt, 575 gpm @ 4130 psi. TO off = 3600 ft-Ibs, TO on = 7000 ft-Ibs. 00:00 - 02:00 2.00 DRILL P PROD1 Drill to 7820' - TD per geologist. 02:00 - 03:30 1.50 DRILL P PROD1 Circulate LO-HI sweep @ 575 GPM upstroke,485 GPM downstroke, 11 ORPM. Monitor well, OK Pump dry job. 03:30 - 06:00 2.50 DRILL P PROD1 Wiper trip to shoe. Good trip. 06:00 - 06:30 0.50 DRILL P PROD1 Service top drive. 06:30 - 07:30 1.00 DRILL P PROD1 Cut and slip drill line 52'. 07:30 - 10:00 2.50 DRILL P PROD1 RIH to 7743'. Filled pipe at 5200'. 10:00 - 12:30 2.50 DRILL P PROD1 Ream last stand to bottom. Circulate LO - HI vis sweep. Spot EZ Glide pill. Monitor well OK. 12:30 - 13:30 1.00 DRILL P PROD1 POH to 5400'. 13:30 - 14:30 1.00 DRILL P PROD1 Break circulation and spot Steel Seal Pill. Monitor well. OK. Pump dry job. 415 GPM @1700 psi. 14:30 - 16:00 1.50 DRILL P PROD1 POH to BHA. 16:00 - 18:30 2.50 DRILL P PROD1 Lay down BHA. 18:30 - 21 :00 2.50 EVAL P PROD1 Rig up Schlumberger. 21 :00 - 23:00 2.00 EVAL P PROD1 RIH to TD. Sat down and worked thru 2936', 4351' and 6285'. No real problems. Start logging out. 23:00 - 00:00 1.00 EVAL P PROD1 Log up 3000'/hr. 00:00 - 02:00 2.00 EVAL P PROD1 Continue to run PEXlBHC sonic log;. 02:00 - 03:00 1.00 EVAL P PROD1 LD logging tools and clear floor. 03:00 - 04:30 1.50 CASE P COMP Pull bowl protector ,install test plug,and change upper variable rams to 7" and test. 04:30 - 05:00 0.50 CASE P COMP PU and make dummy run with casing hanger. 05:00 - 07:00 2.00 CASE P COMP RU casing equipment. 07:00 - 12:00 5.00 CASE P COMP PU and RIH Shoe track. Fill and check floats.RIH to shoe at 2719.MU casing to 8500 ft-Ibs. Fill every joint. Break circulation Printed: 6/24/2002 1: 18:25 PM ) ) BP EXPLORATION Operations Summary . Report Page 4 öf 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/7/2002 6/8/2002 L-109 L-109 DRILL +COMPLETE NABORS NABORS 9ES 5/29/2002 Start: Rig Release: Rig Number: 9-ES Spud Date: 5/30/2002 End: 6/17/2002 From- To Hours Täsk Code NPT Phase Description. of Operations 07:00 - 12:00 5.00 CASE P COMP at 1370' using Franks tool. 12:00 - 12:30 0.50 CASE P COMP Break circulation at shoe 1.5 annular volume staging pump up to 6.5 BPM. 12:30 - 15:00 2.50 CASE P COMP RIH to 4100'. Filling each joint and breaking circulation every 3 joints. 15:00 - 16:00 1.00 CASE P COMP Circulate 1.5 annular volume staging pump to 6.5 BPM. Mud seems somewhat de-hydrated & thick 16:00 - 18:00 2.00 CASE P COMP RIH to 5000'. Filling each joint and breaking circulation every 3 joints. 18:00 - 19:00 1.00 CASE P COMP Circulate 1.5 annular volume staging pump to 6.5 BPM. Treating mud to reduce the YP from 20 to 16. 19:00 - 21 :00 2.00 CASE P COMP RIH to 6000'. Filling each joint and breaking circulation every 3 joints. 21 :00 - 22:00 1.00 CASE P COMP Circulate 1.5 annular volumn staging pump to 7 BPM. 22:00 - 00:00 2.00 CASE P CaMP RIH to 6900'. Filling each joint and breaking circulation every 3 joints. UP wt 210,000 DN wt 144,000. 00:00 - 01 :30 1.50 CASE P CaMP CBU x 1.5 @ 6900' - OK. No losses noted. 01 :30 - 03:00 1.50 CASE P COMP RIH to 7808 - Bottom. Fill each joint and break circulation every 3 joints. Went to bottom no problem. MU casing hanger and landing joint. Land hanger. 03:00 - 03:30 0.50 CASE P COMP Rig down Franks casing circulation tool. Make up cementing head. 03:30 - 06:30 3.00 CEMT P COMP Break circulation and reciprocate long string. Stage up to 7 BPM @ 665 psi. UP 233K DN 160K. No losses. CBU x2 to condition hole while spotting cement trucks and RU. 06:30 - 07:00 0.50 CEMT P COMP Safety meeting for cmt job. 07:00 - 07:45 0.75 CEMT P COMP Cant circ while batch mix 1st stage slurry. 07:45 - 08:00 0.25 CEMT P COMP Pump 5 bbl CW100. Test lines to 4000 psi. Pump 15 bbl CW100 followed by 30 bbl Mudpush XL @ 11.5 ppg. Release bypass plug. 08:00 - 08:15 0.25 CEMT P COMP Pump 1 st Stage: 36 bbl Class G Gasblok cement @ 15.8 ppg. 5 BPM @ 850 psi. Load & launch 1 st stage shut-off plug. 08:15 - 09:00 0.75 CEMT P COMP Displace with rig pump - 7 BPM @ 950 psi. Slow to 2 BPM at 285 bbl away and cant displacement. Reciprocate pipe until 1 0 bbl cement in annulus then land pipe on hanger. Bump shut-off plug at 295 bbl calc - OK. Bleed off pressure - floats holding. CIP 0900 Hrs. 09:00 - 09:30 0.50 CEMT P COMP Load 2nd stage closing plug in head. Pressure up casing and open ES cementer with 3000 psi - OK. Break circ and stage up to 7 BPM. 09:30 - 10:00 0.50 CEMT P COMP Circ and cond hole while batch mixing 2nd stage cement. No losses noted while circ @ 7 BPM. Total circ BU x2. 10:00 - 10:30 0.50 CEMT P COMP Pump 30 bbl CW100 followed by 40 bbl Mudpush XL @ 11.5 ppg. 10:30 - 10:45 0.25 CEMT P COMP Pump 2nd Stage: 49 bbl Class G Gasblok slurry at 15.8 ppg. 5 BPM @ 825 psi. Release closing plug and kick out with 5 bbl water. 10:45 -11:30 0.75 CEMT P COMP Displace with rig pump 6.5-7 BPM @ 875 psi. Slow to 2 BPM prior to landing closing plug. Close ES cementer per Howco procedure & Rep with 2100 psi. Bleed off - acts as if not fully closed. Pressure back up to 2350 psi and hold for 5 min - looks good. Pressure steady and annulus static. CIP @ 1130 Hrs. 11 :30 - 12:00 0.50 CEMT P COMP Bleed off pressure - no ftowback beyond expansion. RD Printed: 6/24/2002 1:18:25 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) BP EXPLORATION QperatiQnsSum mary.. Report L-109 L-109 DRILL +COMPLETE NABORS NABORS 9ES Start: Rig Release: Rig Number: 9-ES 5/29/2002 ) Page 5 of to Spud Date: 5/30/2002 End: 6/17/2002 Date From.;. To Hours Task Code NPT Phase Description of Operations 6/8/2002 11 :30 - 12:00 0.50 CEMT P COMP cementers. 12:00 - 13:30 1.50 CEMT P COMP RD cementers and casing equipment. 13:30 - 14:00 0.50 CASE P COMP Install casing packoff and test to 5000 psi. OK. 14:00 - 15:00 1.00 CASE P COMP Change out 7" rams for variables. 15:00 - 17:30 2.50 CASE P COMP Clean up after cementing operation. 17:30 - 21 :00 3.50 BOPSUR P COMP BOP Test 250/4000 psi. Weekly test moved ahead. Witness of test waived by J. Jones - AOGCC. 21 :00 - 21 :30 0.50 WHSUR P COMP Install wear ring. 21 :30 - 23:00 1.50 CLEAN P COMP MU BHA#4 cleanout assembly and 61/8" ATJ-4 to drill up ES cementer at 5420'. 23:00 - 00:00 1.00 CLEAN P COMP RIH to 1825'. 6/9/2002 00:00 - 01 :00 1.00 CLEAN P COMP RIH to 5370 tag top of cement stringers 50' above ES cmtr. 01 :00 - 03:00 2.00 CLEAN P COMP Drill up cement and ES cementer.250 gpm,850 psi,60 rpm, 3-5k TO, 130 up,98 dn, 114 rt, 8-15k wob. Pump sweep. 03:00 - 04:00 1.00 CLEAN P COMP Circulate Hi vis sweep pill. 04:00 - 05:00 1.00 CLEAN P COMP RIH to 7519' 05:00 - 06:30 1.50 CLEAN P COMP Ream to landing collar at 7723' 500 gpm, 3400 psi, 110 spm, 178 up, 113k dn, 140k rt, No cement on collar. 06:30 - 07:30 1.00 CLEAN P COMP RU and Test casing to 4000 psi for 30 minutes. OK. 07:30 - 09:30 2.00 CLEAN P COMP Change over to 9.1 ppg KCL brine. 09:30 - 09:45 0.25 CLEAN P COMP Monitor well. OK 09:45 - 10:30 0.75 CLEAN P COMP POH to 5208190K up,125k dn. 10:30 - 11 :30 1.00 CLEAN P COMP Spot perf pill. 11 :30 - 12:00 0.50 CLEAN P COMP Perform LOT to 14.8 ppg EMW. Downsqueeze 60 bb110.1 ppg mud down 7" X 9-5/8" annulus to clear same for freeze protect. 12:00 - 14:30 2.50 CLEAN P COMP POH to surface. 14:30 - 20:00 5.50 EVAL P COMP RU SWS. Run USIT cement evaluation tool 7715'-3000'. 20:00 - 00:00 4.00 EVAL N WAIT COMP Cement across Kuparuk good. Log across the Shrader Bluff shows NO cement. Directive from the Asset was to wac another 12 hours and relog. SWS reprocesses log and tweaks some input data and now says there is cement across Schrader?! Plan is still to WOC & run CBUUSIT combo if possible. 6/10/2002 00:00 - 07:00 7.00 EVAL N WAIT COMP Continue WOC per instruction from the Anch. SWS will relog after 06:00 with USIT/CBL combo. General rig housekeeping & maintenance while waiting. 07:00 - 13:30 6.50 EVAL N CEMT COMP Re-run USIT/CBT log across the Shrader Bluffs formation. Uncertainty of the initial USIT log prompted the running of a combo CBUUSIT. This log showed presence of some cement. Send results to Anch for evaluation. 13:30 - 14:00 0.50 EVAL P COMP RD Schlumberger. 14:00 - 15:00 1.00 PERF P COMP PJSM. RU to run perf guns drill pipe conveyed. 15:00 - 16:00 1.00 PERF N WAIT COMP Wait on final approval to perforate the Shrader Bluff injection interval. 16:00 - 17:00 1.00 PERF P COMP PU perforating guns. 4 5/8" Howco Millenium HMX @ 5 SPF. 17:00 - 19:30 2.50 PERF P COMP RIH. 19:30 - 21 :00 1.50 PERF P COMP RU and RIH with Schlumberger. Log in and correct log depth +4'. GR tie-in shows pipe needs to be PU 27' to put guns on depth. POH and LD Schlumberger. 21 :00 - 21 :15 0.25 PERF P COMP PU top drive. PU perforating asembly 27' to place perforating guns on depth 4764-4794,4844-4880,4894-4910,4962- 4985, 5024-5065, and 5096-5108. Pressure well to 2100 psi with 6.14 bbls and bleed off. Perforating guns fired. Monitor well Printed: 6/24/2002 1: 18:25 PM ) ) BP EXPLORATI.ON Operations Summary ~eport Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: Date 6/10/2002 6/11/2002 L-109 L-109 DRILL +COMPLETE NABORS NABORS 9ES From - To Hours Task Code NPT Phase 21:00 - 21:15 0.25 PERF P COMP 21 :15 - 22:00 0.75 PERF P COMP 22:00 - 00:00 2.00 PERF P COMP 00:00 - 00:15 0.25 PERF P COMP 00:15 - 01 :45 1.50 PERF P COMP 01 :45 - 02:15 0.50 PERF P COMP 02:15 - 03:00 0.75 RUNCOIVP COMP 03:00 - 05:00 2.00 RUNCOIVP COMP 05:00 - 06:00 1.00 RUNCOIVP COMP 06:00 - 07:30 1.50 RUNCOIVP COMP 07:30 - 08:00 0.50 RUNCOIVP COMP 08:00 - 09:00 1.00 RUNCOIVP COMP 09:00 - 10:00 1.00 RUNCOIVP COMP 10:00 - 11 :00 1.00 RUNCOIVP COMP 11 :00 - 13:00 2.00 RUNCOIVP COMP 13:00 - 14:00 1.00 RUNCOIVP COMP 14:00 - 15:00 1.00 RUNCOIVP COMP 15:00 - 16:00 1.00 RUNCOIVP COMP 16:00 - 16:30 0.50 RUNCOIVP COMP 16:30 - 21 :30 5.00 RUNCOIVP COMP 21 :30 - 22:30 1.00 RUNCOI'vf\J DPRB COMP 22:30 - 23:30 1.00 RUNCOI'vf\J DPRB COMP 23:30 - 00:00 0.50 RUNCOI'vf\J DPRB COMP 6/12/2002 00:00 - 00:30 0.50 PULL N DPRB COMP 00:30 - 01 :30 1.00 PULL N DPRB COMP 01 :30 - 02:00 0.50 PULL N DPRB COMP 02:00 - 09:00 7.00 PULL N CEMT COMP 09:00 - 10:30 1.50 PULL N CEMT COMP 10:30 - 12:00 1.50 PULL N CEMT COMP 12:00 - 12:30 0.50 PULL N CEMT COMP Page 6 of1 0 Start: Rig Release: Rig Number: 9-ES Spud Date: 5/30/2002 End: 6/17/2002 5/29/2002 Description of Operations initial rate of loss .9 bbl in 5 min. Total losses 4 bbl. Circulate well surface to surface. No losses but got back some gas off btms up. POH to LD perforating guns. Continue to POH to perf guns. LD guns. All shots fired. Clear floor. PU bit, casing scraper, 2 boot baskets. RIH to scrape casing and displace to clean brine. RIH to shut-off baffle @ 7723'. PU off PBTD & circ hi vis sweep. Chase with clean 9.1 ppg KCI circ @ 10 BPM rot @ 110 RPM. Monitor well - static. POH & rack back 25 stds in derrick. Cant POH LDDP. Cut drilling line. Check drawworks brakes. Cant POH LDDP. Rack back HWDP. LD bit, scraper, boot baskets. Recovered 2-3 Ib mise perf debris from baskets. Pull wear ring. Make dummy run with tbg hgr on landing jt. RU tubing tongs & tubing running equpt. PJSM for running tubing. MU 3.5" tailpipe assembly and lower packer. Run 3.5" & 4.5" tubing completion. Pump 65 bbl freeze protect crude down OA while running tbg - simultaneous operation. At end of pumping dead crude to OA, well started flowing as crew PU first jt of 4.5" tbg. Stab safety valve on tubing and shut in well on annular preventer. Pit gain = 5 bbl. Pressures stabilise at: Tbg = 450 psi. IA = 450 psi. OA = 700 psi. Confer with Anch DE and agree plan forward. Bleed total of 10 bbl crude FP fluid from OA to Hot Oil truck and monitor pressures again. Stabilise at: Tbg = 180 psi. IA = 175 psi. OA = 225 psi. Confirms communication from OA to inside of 7" casing via Schrader perfs. OA pressure slowly building back up. Open well up thru choke to bleed any trapped pressure from tbg & IA - OK. Open annular to observe well. V. slight flow with initial 1 bbl gain - then stabilised. No flow - well stable. OA pressure = 275 psi. TBG & IA open and stable. RU to circ well via tubing & prep to pull completion. Bleed off tubing and IA pressure to zero. Open annular and monitor well - static. OAP - 320 psi. Circ well surf»surf 3 BPM @ 145 psi. OAP builds to 375 psi. Monitor well 30 min - static. Pull and LD 3.5" completion tubing and jewelry. Rig down casing tools. Change to short bails. Wait on way forward. General rig maintenance. Service top drive. PM work on Gen #2. Bleed OA from 300 to 175 psi. Pump 1.5 bbl to casing and pressure incr to 450 psi. OA increases to 250 psi. Bleed back OA to 175 psi with corresponding drop in csg pressure to 275 psi. Seems to confirm presence of communication channel behind 7" casing to surface. Bleed casing to zero - OA=225 psi. Printed: 6/24/2002 1: 18:25 PM ) ) BP EXPLORATION Operatiol1sSummary. Report Page 7 of 10 Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: L-109 L-109 DRILL +COMPLETE NABORS NABORS 9ES Start: Rig Release: Rig Number: 9-ES 5/29/2002 Spud Date: 5/30/2002 End: 6/17/2002 Date From - To Hours Task Code NPT Phase Description. of Operations 6/12/2002 12:30 - 13:00 0.50 PULL N CEMT CaMP Monitor well - OK. Install wear ring. 13:00 - 15:00 2.00 PULL N CEMT CaMP PU 93 singles 4" DP. 15:00 - 16:00 1.00 PULL N CEMT CaMP Cant RIH with stands from derrick to 5200'. 16:00 - 17:00 1.00 PULL N CEMT CaMP Circ @ 490 GPM. Rot 100 RPM. Reciprocate to clean up wellbore for EZSV's. 17:00 - 18:30 1.50 PULL N CEMT CaMP Monitor well - static. Pump dry job. POH to set retainers. 18:30 - 19:00 0.50 PULL N CEMT CaMP PJSM to prior to RU SWS. 19:00 - 00:00 5.00 PULL N CEMT CaMP RU SWS. Run 5.95" Gauge ring/JB to 5300' MD. Run & set EZSV @ 5150' ELMD. Run & set FasDrill @ 4710' ELMD. RD SWS. 6/13/2002 00:00 - 00:30 0.50 PULL N CEMT CaMP RD SWS. Hook up hard line to flowback tank & test to 4000 psi. 00:30 - 03:00 2.50 REMCM-N CEMT CaMP MU star guide stinger & RIH on DP to 4688'. 03:00 - 03:30 0.50 REMCM-N CEMT CaMP MU head pin & hose forcement job. 03:30 - 04:00 0.50 REMCM-N CEMT CaMP Break circ above FasDrill 2 BPM @ 80 psi. 04:00 - 07:00 3.00 REMCM-N CEMT CaMP Sting in to retainer and open choke on OA. Attempt to establish circulation to OA - does not appear to be circulating. Pump 20 bbl thru retainer with only approx 1 bbl rtns from OA. Switch to pump dn OA w/ rtns up DP - no eire, only injection. Confer w/ Anch DE & agree to move to squeeze cement to perfs. 07:00 - 07: 15 0.25 REMCM-N CEMT CaMP PJSM for squeeze cement job. 07:15 - 08:15 1.00 REMCM-N CEMT CaMP Batch up slurry. Unsting from retainer. Close bag and open choke. Pump 5 bbl CW100. Test lines to 3500 psi. Pump 10 bbl CW100 followed by 20 bb115.8 ppg Class G slurry. Sting in to retainer and pump remaining 14 bbl slurry to DP. Displace with mud squeezing away. Getting some returns when squeezing. 08:15 - 09:15 1.00 REMCM-N CEMT CaMP Cant squeezing cement below retainer @ 2 BPM. Initial pressure 260 psi incr to 870 psi at 25 bbl away. Hesitate squeeze last 10 bbl slurry to perfs with final circ pressure of 1060 psi @ 2 BPM. CIP at 0910 Hrs. Had circ to OA at surface during job with returns diminishing towards end of squeeze. 35 bbl slurry squeezed with approx 15 bbl returns from OA @ surface. 09:15 - 10:00 0.75 REMCM-N CEMT CaMP Unsting from retainer & eirc hole clean @ 6 BPM. CBU x2 while recip pipe. 10:00 - 12:30 2.50 REMCM-N CEMT CaMP RD cmt equp't & hose. Blow dn lines. POH with stinger & LD same. 12:30 - 12:45 0.25 REMCM-N CEMT CaMP PJSM for testing BOPE. 12:45 - 13:00 0.25 REMCM-N CEMT CaMP Install test plug. 13:00 - 17:00 4.00 BOPSUR N CEMT CaMP Test BOPE 250/4000 psi, annular 3500 psi. No failures. Test witnessed by C. Scheve - AOGCC. Start pumping 3 bbl mud to OA each hour to confirm OA not cemented up. Pump total of 12 bbl from 1630 hrs to 1930 hrs - 800 psi @ 1.5 bpm OA appears to be open. RIU cementers and Little Red. 17:00 - 17:30 0.50 REMCM-N CEMT CaMP Install wear bushing. 17:30 - 21:10 3.67 REMCM-N CEMT CaMP P/U BHA #5 and 4" DP singles. RIH to 4550'. 21:10 - 21:25 0.25 REMCM-N CEMT CaMP PJSM review cement procedures and job assignments. 21 :25 - 22:00 0.58 REMCM-N CEMT CaMP PT cement and FP oil lines to 3500 psi. (replace oil hose f/ Little Red) 22:00 - 23:00 1.00 REMCM-N CEMT CaMP Bullhead 20 bb115. 7 ppg Artie Set I cement then 5 bbl water followed by 11 bbl mud then 65 bbl dead oil into 9 5/8" X 7" Printed: 6/24/2002 1:18:25 PM ) ) BP EXPLORATION Operations Summary Report Page 80f 1 0 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-109 L-109 DRILL +COMPLETE NABORS NABORS 9ES Start: Rig Release: Rig Number: 9-ES 5/29/2002 Spud Date: 5/30/2002 End: 6/17/2002 Date From - To Hours Task Code NPT Phase Description of Operations 6/13/2002 22:00 - 23:00 1.00 REMCM-N CEMT COMP annulus. Injection @ 2.4 bpm +/- 825 psi fluctuating with fluid density. Estimated TOC 2900 MD. Estimated FP to 2200' TVD 23:00 - 00:00 1.00 REMCM-N CEMT COMP Slowdown lines rId cementers. 6/14/2002 00:00 - 00:30 0.50 REMCM-N CEMT COMP RIH tag "Fasdrill" packer at 4715'. 00:30 - 01 :30 1.00 REMCM-N CEMT COMP Drill packer w/ 80 rpm 6-8k wOb, pumping hi-vis sweeps. 01 :30 - 08:30 7.00 REMCM-N CEMT COMP Drill cement f/4760' to 5130' 6-7k 70-100 rpm 08:30 - 10:30 2.00 REMCM-N CEMT COMP Tag EZSV at 5150'. Drill up w/60-80 rpm, 4-6k wOb, pump hi-vis pills. 10:30 - 12:00 1.50 REMCM-N CEMT CaMP Continue RIH to landing collar at 7723'. 12:00 - 13:00 1.00 REMCM-N CEMT COMP Circulate hi-vis sweep. 13:00 - 14:00 1.00 REMCM-N CEMT COMP TOH to 5300' 14:00 - 15:00 1.00 REMCM-N CEMT COMP Circulate displace well to clean 9.1 ppg brine. Pump 60 bbl perf pill. 15:00 - 17:30 2.50 REMCM-N CEMT COMP TOH for SWS USIT log. Lay in 9.1 ppg perf pill. 17:30 - 18:00 0.50 REMCM-N CEMT COMP PJSM w/ SWS hands. Rig SWS. 18:00 - 20:30 2.50 REMCM-N CEMT COMP RIH w/logging tools. Log f/ 5500' to 2700' TOH. R/D SWS. USIT log shows good cement bond across selected perf intervals. 20:30 - 21 :00 0.50 REMCM-N CEMT COMP Service top drive and crown. 21 :00 - 22:00 1.00 PERFRE N CEMT COMP PJSM w/ HOWCO perf crew. P/U perf guns. 22:00 - 00:00 2.00 PERFRE N CEMT COMP TIH w/ perf guns. 6/15/2002 00:00 - 00:45 0.75 PERFRE N CEMT COMP Finish RIH with 4 5/8" 5 SPF Scallop perf guns. P/U and postion top shot at preliminary depth of 4795'. (pip tag @ 4690') 00:45 - 02:00 1.25 PERFRE N CEMT COMP PJSM w/ SWS crew to run correlation log. R/U logging tools. RIH log GR f/4750' - 4400'. TOH make -3' correction to pip tag depth. R/D SWS 02:00 - 03:00 1.00 PERFRE N CEMT COMP PJSM w/ crews review job assignments (guns set to fire w/ 1500 psi minimum). P/U and position top shot at 4764'. Close VSR and HCR. Pressure up to fire guns. Seeing pressure bleed off. Chk for surface leaks - none. Squeezed perfs must be breaking down. Cont to pressure up to 2100 psi to arm firing head. Sleed off pressure. Guns fired after approx 4 1/2 min wait according to shot detection tape. Perfs: 148' net at selected intervals between 4764' - 5108' 03:00 - 04:00 1.00 PERFRE N CEMT COMP Open VSR rams. Monitor well - no flow. Circulate and reciprocate pipe. Shutdown and monitor well. Static. No loss. No gain. 04:00 - 06:00 2.00 PERFRE N CEMT COMP POH with guns. 06:00 - 09:00 3.00 PERFRE N CEMT COMP Guns at surface - top gun did not detonate. PJSM for LD live guns. Essential personnel only on rig floor. Pull & LD guns. NO GUNS FIRED. Neither firing head activated and all guns dry. Confer with Anch DE. Asset wants to re-try perforating. Will run different firing head assembly with Champ packer to isolate squeezed (now leaking) perfs from firing head activation pressure. Clear rig floor. 09:00 - 09:30 0.50 PERFRE N CEMT COMP Inspect brake bands. Service top drive. 09:30 - 10:30 1.00 PERFRE N CEMT COMP MU bit, boot baskets, casing scraper, DC's HWDP. 10:30 - 12:30 2.00 PERFRE N CEMT COMP RIH to 5380'. 12:30 - 13:30 1.00 PERFRE N CEMT COMP Circulate at 600 GPM to clean hole of debris from drilling retainers prior to re-running guns with Howco Champ packer. Spot new perf pill from 5300 to 3500'. 13:30 - 15:30 2.00 PERFRE N CEMT COMP POH with scraper & boot baskets. Printed: 6/24/2002 1 :18:25 PM ') ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L -1 09 L-109 DRILL +COMPLETE NABORS NABORS 9ES Hours Task Code NPT Phase 6/15/2002 15:30 - 16:00 0.50 PERFRE N CEMT COMP 16:00 - 16:15 0.25 PERFRE N CEMT COMP 16:15 - 18:00 1.75 PERFRE N CEMT COMP 18:00 - 20:00 2.00 PERFRE N CEMT COMP 20:00 - 20:40 0.67 PERFRE N CEMT COMP 20:40 - 21 :30 0.83 PERFRE N CEMT COMP 21 :30 - 22:00 0.50 PERFRE N CEMT COMP 22:00 - 22:40 0.67 PERFRE N CEMT COMP 22:40 - 00:00 1.33 PERFRE N CEMT COMP 6/16/2002 00:00 - 01 :30 1.50 PERFRE N CEMT COMP 01 :30 - 01 :45 0.25 PERFRE N CEMT COMP 01 :45 - 03:00 1.25 PERFRE N CEMT COMP 03:00 - 03:30 0.50 PERFRE N CEMT COMP 03:30 - 04:30 1.00 CLEAN N CEMT COMP 04:30 - 07:30 3.00 CLEAN N CEMT COMP 07:30 - 08:30 1.00 CLEAN N CEMT CaMP 08:30 - 12:00 3.50 RUNCOIVN CEMT COMP 12:00 - 12:15 0.25 RUNCOIVN CEMT COMP 12:15 - 13:00 0.75 RUNCOIVN CEMT COMP 13:00 - 14:30 1.50 RUNCOIVN CEMT COMP 14:30 - 16:00 1.50 RUNCOIVN CEMT COMP 16:00 - 17:00 1.00 RUNCOIVN CEMT COMP 17:00-17:15 0.25 RUNCOIVN CEMT COMP 17:15-22:00 4.75 RUNCOIVN CEMT COMP 22:00 - 00:00 2.00 RUNCOrvP CaMP 6/17/2002 00:00 - 00: 15 0.25 RUNCOrvP CaMP 00:15 - 05:00 4.75 RUNCOrvP COMP 05:00 - 07:00 2.00 RUNCOrvP CaMP 07:00 - 09:00 2.00 RUNCOrvP COMP 09:00 - 10:30 1.50 RUNCOrvP COMP 10:30 - 12:00 12:00 - 13:00 13:00 - 15:00 15:00 - 16:30 1.50 RUNCOrvP 1.00 RUNCOrvP 2.00 WHSUR P 1.50 WHSUR P COMP COMP COMP COMP Start: Rig Release: Rig Number: 9-ES Spud Date: 5/30/2002 End: 6/17/2002 5/29/2002 Description of Operations. LD BHA. Minor amt of metal debris recovered in boot baskets. PJSM with NAD, Howco, BPX on PU perforating guns. P/U 344' perf guns (148'net) Howco 4 5/8" Scallop 5 SPF and Champ packer assembly. TIH to 5124'. From pipe tally "pip" tag @ 4566'. PJSM w/ SWS and crews. R/U SWS RIH w/ SWS gr tie-in log. Log from 4650' to 4400'. Correction of -3' for "pip" tag. OOH w/ SWS and R/D same. M/U top drive. P/U 11' to put top shot on depth at 4764' MD. Set Champ packer. Close annular. Pressure up annulus to 2600 psi and hold 1 min. Bleed off. Guns fired after 6 mins. Confirm with pipe movement and recorder. Unseat packer initial +/- 3 bblloss. Monitor well - static. Slowly reciprocate pipe and make full circulation. Shutdown monitor well - static no gains/no loss. TOH to perf guns LID Howco Champ packer assembly. PJSM on laying down perf guns. LID 344' perf gun assembly. All guns fired. Perf Intervals: 4764'-4794' 4844'-4880' 4894'-4910 4962'-4985' 5024'-5065' 5096'-5108' 4 5/8" HMX 39 gr Scallop guns 5 spf Clear floor of perf guns and tools. MU bit, boot baskets, casing scraper, DC's HWDP. RIH w/ scrapper tag at 7723'. Circulate hole with clean 9.1 ppg brine. TOH stand back 25 stds DP PJSM. LID DP. Crew change. PJSM LID DP and cut/slip drill line. Cut and slip 88' drill line. LID remaining DP. Standback 6 stds HWDP. LID DC's scraper and boot baskets. Clear floor and pull wear bushing. PJSM running completion string. R/U running tools. P/U and run 3 1/2" 9.2# L-80 TCII tbg (2500 ft Ibs torque) with completion equipment as per tally. MU XO 3.5" x 4.5" & continue running 41/2" tubing making up to 2900 ft Ibs torque. Crew change PJSM running completion string. Continue running 3 1/2" x 4 1/2" completion string. MU hanger and landing joint. Run down land and torque lockdowns. Reverse circ w/1 00 bbls clean brine followed by 159 bbls corrosion inhibited brine. Pressure up on tbg to 2800 psi and set lower Baker S-3 packer. Hold for 10 min then pressure up to 4200 to set the upper Baker Premier packer. Hold for 30 min then bleed off to 2000 psi. Pressure up annulus to 4000 psi hold and test. No leak-off. Bleed off tubing pressure to shear RP valve in lower GLM. Back out landing joint. Set 2-way check and test to 2800 psi. RID tubing equipment and clear floor. NID BOP's. N/U FMC 11" 5M x 4 1/8" 5M adapter fig and 4 1/8" 5M production tree. Test same to 5000 psi -OK. Printed: 6/24/2002 1: 1 8:25 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/17/2002 ') ) BP EXPLORATION Operations Summary. Report L-109 L-109 DRILL +COMPLETE NABORS NABORS 9ES From- To Hours Task Code NPT Phase 16:30 - 17:30 17:30 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 21 :00 21 :00 - 22:00 1.00 WHSUR P 0.50 WHSUR P 1.00 WHSUR P COMP CaMP CaMP 1.00 WHSUR P 1.00 WHSUR P 1.00 RIGD P COMP COMP COMP Page 1 Oof 10 Start: Rig Release: Rig Number: 9-ES Spud Date: 5/30/2002 End: 6/17/2002 5/29/2002 Descri ptionof Operations R/U lubricator and pull TWC. R/U Little Red to 7" x 4 1/2" annulus and test lines to 3k. Reverse in 85 bbls diesel for freeze protection at 2.3 bpm 1200 psi. U-tube diesel to tubing to FP tubing & IA to 2420'. Set BPV and test to 1000 psi - ok. Rigdown and make preparations for move to L-108i. Shut SSSV to adjacent well L-116. Start gas lift bleed-off on L-106, 2 slots from L-108i for downhole close approach. Nabors 9ES released from L-109i at 2200 hrs 6-17-2002 Printed: 6/24/2002 1: 18:25 PM Well: Field: API: Permit: ) ) L -1 09 Prudhoe Bay Field / Borealis 50-029-23046-00 201-201 Rig Accept: OS/29/02 Rig Spud: 05/30/02 Rig Release: 06/17/02 Drilling Rig: Nabors 9ES POST RIG WORK 07/16/02 RAN JEWELRY LOG AND PERFORATED TWO 30' INTERVALS (7484'-7514' & 7524'-7554') WITH 2-1/2" POWERJET GUNS, GUNS WERE ORIENTED 10 DEG OFF LOW SIDE PER ENGINEERING REQUEST. ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Prudhoe Bay / Borealis Well. . . . . . . . . . . . . . . . . . . . .: L-109i API number...............: 50-029-23046-00 Engineer. . . . . . . . . . . . . . . . .: Rene Franco COUNTY:..................: Nabors 9 ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS.. . . . . . . . . .: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: DRILL FLOOR GL above permanent.......: 47.90 ft KB above permanent.......: N/A DF above permanent.......: 76.40 ft ----- vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: N 70.3501325 Departure (+E/W-)........: W 149.324608 Azimuth from rotary table to target: 179.76 degrees [(c)2002 Anadrill IDEAL ID6_1C_10J 6-Jun-2002 05:35:45 Spud date. . . . . . . . . . . . . . . . : Last survey date..... ....: Total accepted surveys. ..: MD of first survey.......: MD of last survey... ... ..: Page 1 of 4 30-May-02 06-Jun-02 89 0.00 ft 7820.00 ft --' ----- Geomagnetic data ---------------------- Magnetic model.. .........: BGGM version 2001 Magnetic date. ...........: 31-May-2002 Magnetic field strength..: 1149.51 HCNT Magnetic dec (+E/W-).. ...: 26.01 degrees Magnetic dip...... .......: 80.76 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: H. . . . . . . . . . . . . . : Dip. . . . . . . .. . . . : of G...........: of H...........: of Dip.........: Criteria --------- 1002.68 mGal 1149.51 HCNT 80.76 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT' (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-). ....: 26.01 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 26.01 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ..,. ....: No degree: 0.00 -' ANADRILL SCHLUMBERGER Survey Report --- -------- -------- Seq Measured # depth (ft) 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 ----.----- -------- 1 2 3 4 5 0.00 50.00 100.00 150.00 173.00 263.00 355.00 447.00 539.00 632.00 724.00 819.00 851.29 943.94 1036.05 1131.19 1224.11 1318.32 1411.80 1506.24 1598.18 1689.27 1782.33 1876.44 1969.59 2062.33 2154.29 2249.53 2342.35 2436.23 ------ ------ Incl angle (deg) ------ ------ 0.00 0.30 0.36 0.28 0.22 0.15 1.49 2.26 3.33 4.18 5.17 6.32 6.72 8.14 10.28 12.17 13.86 14.53 16.18 15.86 17.89 18.38 19.59 20.68 20.20 21.50 23.57 25.65 27.49 30.63 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 177.67 353.15 2.94 359.66 1.14 179.41 163.24 161.52 172.34 174.98 179.68 180.73 181.85 182.88 181.08 176.02 177.82 177.64 178.09 178.80 180.21 182.87 180.20 176.69 176.86 175.52 176.45 177.17 175.68 174.99 ------ ------ 0.00 50.00 50.00 50.00 23.00 90.00 92.00 92.00 92.00 93.00 92.00 95.00 32.29 92.65 92.11 95.14 92.92 94.21 93.48 94.44 91.94 91.09 93.06 94.11 93.15 92.74 91.96 95.24 92.82 93.88 -------- -------- TVD depth (ft) -------- -------- 0.00 50.00 100.00 150.00 173.00 263.00 354.99 446.94 538.83 631.63 723.32 817.84 849.92 941.79 1032.71 1126.03 1216.56 1307.89 1398.03 1488.80 1576.78 1663.35 1751.34 1839.70 1926.99 2013.65 2098.59 2185.17 2268.19 2350.24 6-Jun-2002 05:35:45 -------- -------- Vertical section (ft) -------- -------- 0.00 -0.13 -0.42 -0.70 -0.80 -0.85 0.42 3.29 7.66 13.71 21.20 30.71 34.37 46.34 61.07 79.57 100.47 123.55 148.29 174.35 201.03 229.37 259.62 291.99 324.48 357.42 392.58 432.19 473.63 519.09 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 0.00 0.13 0.42 0.70 0.80 0.85 -0.41 -3.28 -7.65 -13.70 -21.19 -30.70 -34.36 -46.33 -61.06 -79.56 -100.45 -123.54 -148.27 -174.32 -201.01 -229.34 -259.60 -291.97 -324.45 -357.38 -392.53 -432.13 -473.56 -519.00 0.00 -0.02 -0.02 -0.02 -0.02 -0.01 0.34 1.26 2.19 2.84 3.16 3.12 3.03 2.53 2.05 2.58 3.69 4.60 5.52 6.23 6.44 5.67 4.88 5.78 7.61 9.82 12.27 14.47 17.08 20.80 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 0.00 0.13 0.42 0.70 0.80 0.85 0.53 3.51 7.96 13.99 21.42 30.85 34.50 46.40 61.10 79.60 100.52 123.62 148.37 174.44 201.11 229.41 259.65 292.03 324.54 357.51 392.73 432.37 473.87 519.42 0.00 353.15 356.82 358.70 358.90 359.28 141.02 159.06 164.05 168.28 171.52 174.20 174.96 176.88 178.08 178.14 177.90 177.87 177.87 177.95 178.17 178.58 178.92 178.87 178.66 178.43 178.21 178.08 177.93 177.71 2 of 4 ----- DLS (deg/ 100f) ----- 0.00 0.60 0.16 0.16 0.26 0.41 1.46 0.84 1.29 0.93 1.15 1.22 1.30 1.54 2.34 2.24 1.87 0.71 1.77 0.40 2.25 1.06 1.60 1.73 0.52 1.49 2.28 2.21 2.11 3.36 ----- ------ ------ Srvy tool type Tool qual type ----- ------ ------ TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR ~- GYR GYR MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA -- MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ANADRILL SCHLUMBERGER Survey Report --- -------- -------- Seq Measured # depth (ft) 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 -------- -------- 2530.36 2624.68 2675.82 2714.45 2806.23 2899.97 2993.04 3086.66 3179.99 3273.54 3365.70 3459.28 3553.45 3646.37 3738.86 3830.95 3924.23 4017.12 4109.27 4204.53 4298.45 4391.57 4485.64 4578.75 4671.99 4765.18 4858.38 4951.53 5044.97 5137.31 ------ ------ Incl angle (deg) ------ ------ 33.13 33.18 32.88 32.77 32.88 33.04 33.10 33.21 32.84 33.16 33.36 33.56 33.59 33.38 33.67 33.87 33.49 34.29 34.54 35.30 35.77 36.16 36.05 36.21 36.79 36.55 36.09 35.21 33.88 32.54 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 174.26 173.85 174.25 175.30 177.81 177.55 177.70 177.36 177.29 176.30 175.83 175.13 174.58 175.68 177.72 177.92 177.87 177.45 176.81 176.47 175.59 175.22 176.46 175.70 176.61 178.83 180.98 181.03 184.21 185.00 ------ ------ 94.13 94.32 51.14 38.63 91.78 93.74 93.07 93.62 93.33 93.55 92.16 93.58 94.17 92.92 92.49 92.09 93.28 92.89 92.15 95.26 93.92 93.12 94.07 93.11 93.24 93.19 93.20 93.15 93.44 92.34 -------- -------- TVD depth (ft) -------- -------- 2430.16 2509.13 2552.00 2584.47 2661.59 2740.25 2818.24 2896.62 2974.87 3053.33 3130.39 3208.46 3286.92 3364.42 3441.53 3518.08 3595.70 3672.81 3748.83 3826.94 3903.37 3978.74 4054.74 4129.94 4204.90 4279.65 4354.74 4430.43 4507.40 4584.66 6-Jun-2002 05:35:45 -------- -------- Vertical section (ft) -------- -------- 568.60 619.92 647.66 668.52 718.19 769.15 819.90 871.06 921.88 972.76 1023.20 1074.65 1126.54 1177.64 1228.64 1279.80 1331.50 1383.26 1435.29 1489.74 1544.21 1598.74 1654.04 1708.82 1764.17 1819.78 1874.98 1929.25 1982.16 2032.55 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- -568.49 -619.80 -647.52 -668.38 -718.03 -768.99 -819.73 -870.88 -921.69 -972.56 -1022.99 -1074.42 -1126.29 -1177.37 -1228.36 -1279.51 -1331.20 -1382.96 -1434.97 -1489.41 -1543.86 -1598.37 -1653.66 -1708.43 -1763.76 -1819.36 -1874.56 -1928.84 -1981.75 -2032.16 25.47 30.81 33.70 35.61 38.59 40.66 42.76 44.97 47.34 50.19 53.66 57.73 62.40 66.75 69.69 71.64 73.54 75.65 78.26 81.46 85.24 89.62 93.64 97.40 101.11 103.33 103.43 102.48 100.08 96.03 Page --------------- --------------- Total displ ( ft) At Azim Cdeg) --------------- --------------- 569.06 620.56 648.40 669.32 719.07 770.06 820.84 872.04 922.91 973.86 1024.39 1075.97 1128.02 1179.26 1230.33 1281.51 1333.23 1385.02 1437.10 1491.63 1546.21 1600.88 1656.31 1711.20 1766.66 1822.30 1877.41 1931.56 1984.28 2034.43 177.44 177.15 177.02 176.95 176.92 176.97 177.01 177.04 177.06 177.05 177.00 176.92 176.83 176.76 176.75 176.80 176.84 176.87 176.88 176.87 176.84 176.79 176.76 176.74 176.72 176.75 176.84 176.96 177.11 177.29 3 of 4 ----- DLS (deg/ 100f) 2.69 0.24 0.73 1.50 1.49 0.23 0.11 0.23 0.40 0.67 0.35 0.46 0.32 0.69 1.26 0.25 0.41 0.90 0.48 0.82 0.74 0.48 0.79 0.51 0.85 1.45 1.45 0.95 2.40 1.52 ----- ------ ------ Srvy tool type Tool qual type ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD Incl. Only MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA -"" MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA --' MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ANADRILL SCHLUMBERGER Survey Report --- ---------- -------- Seq Measured # depth (ft) 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 -------- -------- 5231.42 5323.24 5417.26 5511.59 5604.61 5697.50 5790.38 5884.12 5976.94 6071.54 6164.66 6258.05 6352.31 6445.55 6538.32 6630.74 6724.13 6816.45 6911.73 7005.69 7099.12 7193.15 7286.15 7380.44 7474.40 7566.14 7658.52 7735.15 7820.00 ------ ------ Incl angle (deg) ------ ------ 30.97 29.34 28.46 28.68 28.90 28.99 29.12 29.00 28.62 28.27 28.13 27.65 27.42 26.69 26.25 27.38 28.46 29.72 28.65 27.44 26.08 25.05 24.39 23.43 22.65 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 187.56 187.14 186.61 186.61 186.31 185.78 186.45 186.87 186.25 185.92 185.52 185.62 185.83 185.32 185.50 185.69 186.17 186.06 185.77 185.95 186.43 186.29 186.28 185.66 185.50 22.65 182.85 22.93 182.21 22.34 183.28 22.34 183.28 ------ ------ 94.11 91.82 94.02 94.33 93.02 92.89 92.88 93.74 92.82 94.60 93.12 93.39 94.26 93.24 92.77 92.42 93.39 92.32 95.28 93.96 93.43 94.03 93.00 94.29 93.96 91.74 92.38 76.63 84.85 [(c)2002 Anadrill IDEAL ID6_1C_10] -------- -------- TVD depth (ft) -------- -------- 4664.68 4744.07 4826.38 4909.23 4990.75 5072.04 5153.23 5235.17 5316.50 5399.68 5481.74 5564.29 5647.87 5730.91 5813.95 5896.43 5978.95 6059.62 6142.81 6225.73 6309.15 6393.98 6478.45 6564.65 6651.11 6-Jun-2002 05:35:45 -------- -------- Vertical section (ft) -------- -------- 2081.75 2127.47 2172.56 2217.35 2261.84 2306.52 2351.35 2396.55 2440.97 2485.75 2529.52 2572.98 2616.32 2658.51 2699.66 2741.13 2784.61 2829.21 2875.41 2919.33 2961.13 3001.44 3040.08 3078.07 3114.65 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- -2081.39 -2127.13 -2172.24 -2217.05 -2261.57 -2306.27 -2351.12 -2396.35 -2440.78 -2485.59 -2529.37 -2572.85 -2616.21 -2658.42 -2699.58 -2741.08 -2784.57 -2829.20 -2875.41 -2919.36 -2961.18 -3001.50 -3040.16 -3078.17 -3114.77 6735.78 3149.87 -3149.99 6820.95 3185.61 -3185.74 6891.68 3215.06 -3215.20 6970.16 3247.25 -3247.40 90.63 84.73 79.29 74.09 69.05 64.32 59.52 54.23 49.12 44.35 39.96 35.72 31.37 27.25 23.35 19.29 14.77 9.99 5.20 0.69 -3.84 -8.34 -12.60 -16.58 -20.15 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 2083.36 2128.82 2173.69 2218.29 2262.62 2307.17 2351.87 2396.96 2441.28 2485.98 2529.69 2573.10 2616.40 2658.56 2699.68 2741.14 2784.61 2829.22 2875.42 2919.36 2961.18 3001.52 3040.19 3078.21 3114.83 177.51 177.72 177.91 178.09 178.25 178.40 178.55 178.70 178.85 178.98 179.09 179.20 179.31 179.41 179.50 179.60 179.70 179.80 179.90 179.99 180.07 180.16 180.24 180.31 180.37 -22.72 3150.08 180.41 -24.30 3185.84 180.44 -25.71 3215.30 180.46 -27.56 3247.52 180.49 4 of 4 ----- DLS (deg/ 100f) ----- 2.20 1.79 0.97 0.23 0.28 0.29 0.38 0.25 0.52 0.41 0.25 0.52 0.26 0.82 0.48 1.23 1.18 1.37 1.13 1.29 1.47 1.10 0.71 1.05 0.83 ------ ------ Srvy tool type Tool qual type ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA -- MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA --- 1.11 MWD_IFR_MSA 0.40 MWD_IFR_MSA 0.94 MWD_IFR_MSA 0.00 Projected to TD õ Report Date: Client: Field: Structure I Slot: Well: Borehole: UWI/API#: Survey Name I Date: Tort 1 AHD 1 DDII ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid N/E Y1X: Grid Convergence Angle: Grid Scale Factor: L-109 Survey Report - Geodetic 6-Jun-02 BP Exploration Alaska Prudhoe Bay Unit - WOA (Drill Pads) L-Pad / L-1 09 L-109 L-109 500292304600 L-109/ June 6,2002 79.480° /3259.81 ft /5.463/ 0.46E NAD27 Alaska State Planes. Zone 4, US Fee1 N 70 21 0.477, W 149 19 28.58~ N 5978097.980 ftUS, E 583188.270 ftUS -+D.63606380° 0.99990786 Station ID MD I Incl (ft) (°) 0.00 0.00 50.00 0.30 100.00 0.36 150.00 0.28 173.00 0.22 263.00 0.15 355.00 1.49 447.00 2.26 539.00 3.33 632.00 4.18 724.00 5.17 819.00 6.32 851.29 6.72 943.94 8.14 1036.05 10.28 1131.19 12.17 1224.11 13.86 1318.32 14.53 1411.80 16.18 1506.24 15.86 L-109 ASP Final Survey. xis - Azim (°) 0.00 353.15 2.94 359.66 1.14 TVD I (ft) 0.00 50.00 100.00 150.00 173.00 179.41 163.24 161.52 172.34 174.98 263.00 354.99 446.94 538.83 631.63 179.68 723.32 180.73 ~. 817.84 181.85 849.92 182.88 941.79 181.08 1032.71 176.02 1126.03 177.82 1216.56 177.64 1307.89 178.09 1398.03 178.80 1488.80 VSec (ft) 0.00 -0.13 -0.42 -0.70 -0.80 -0.85 0.41 3.27 7.63 13.68 21.16 30.67 34.34 46.31 61.04 79.53 100.42 123.49 148.22 174.26 N/.S (ft) 0.00 0.13 0.42 0.70 0.80 0.85 -0.41 -3.28 -7.65 -13.70 -21.19 -30.70 -34.36 -46.33 -61.06 -79.56 -100.45 -123.54 -148.27 -174.32 Page 1 of 3 Survey 1 DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed 1 Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: Schlumberger Minimum Curvature / Lubinski 180.490° N 0.000 ft. E 0.000 f1 KB 76.400 ft relative to MSL 44.100 ft relative to MSL +25.89r 57498.676 nT 80.774° June 05, 2002 BGGM 2002 True North +25.897° Well Head --~'" E/.W I (ft) 0.00 -0.02 -0.02 -0.02 -0.02 Grid Coordinates Geographic Coordinates Northing I Easting ~titJ.lde I I I Longitude (ftUS) (ftUS) - ' - - / 5978097.98 583188.27 N 70 21 0.477 W 1491928.589 5978098.11 583188.25 N 7021 0.478 W 149 19 28.590 5978098.40 "'d583188.24 N 70 21 0.481 W 14919 28.590 5978098.68 583188.2tr/ N 70 ~1 0.484 W 14919 28.590 5978098.78 583188.25 N 7021 0.485 W 1491928.590 DLS (0/100ft) 0.60 0.16 0.16 0.26 -0.01 0.41 5978098.83 583188.25 N 7021 0.485 W 1491928.590 0.34 1.46 5978097.57 583188.61 N 7021 0.473.W 149 1928.580 1.26 0.84 5978094.71 583189.56 N 70 21 0.445 W 149 1928.553 2.19 1.29 5978090.36 583190.54 N 70 21 0.402 W 149 19 28.526 2.84 0.93 5978084.31 583191.26 N 7021 0.342 W 1491928.506 ,~/ 3.16 1.15 5978076.83 583191.66 N 7021 0.269 W 149 1928.497 3.12 1.22 5978067.32 583191.73 N 70 21 0.175 W 14919 28.498 3.03 1.30 5978063.66 583191.68 N 70 21 0.139 W 14919 28.501 2.53 1.54 5978051.68 583191.31 N 7021 0.021 W 1491928.516 2.05 2.34 5978036.95 583190.99 N 70 20 59.876 W 149 19 28.530 2.58 2.24 5978018.46 583191.74 N 70 20 59.694 W 14919 28.514 3.69 1.87 5977997.58 583193.07 N 70 20 59.489 W 149 19 28.482 4.60 0.71 5977974.51 583194.24 N 70 20 59.262 W 149 19 28.455 5.52 1.77 5977949.79 583195.43 N 7020 59.019 W 149 1928.428 6.23 0.40 5977923.75 583196.43 N 70 20 58.762 W 149 19 28.407 6/12/2002-10:52 AM Grid Coordinates Geographic Coordinates Station JD MD Incl Azim TVD VSec N/.S EJ.W I DLS Northing Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (o/100ft) (ftUS) (ftUS) 1598.18 17.89 180.21 1576.78 200.95 -201.01 6.44 2.25 5977897.07 583196.94 N 70 20 58.500 W 149 19 28.401 1689.27 18.38 182.87 1663.35 229.29 -229.34 5.67 1.06 5977868.74 583196.48 N 70 20 58.221 W 1491928.424 1782.33 19.59 180.20 1751.34 259.55 -259.60 4.88 1.60 5977838.48 583196.03 N 70 20 57.924 W 149 1928.447 1876.44 20.68 176.69 1839.70 291.91 -291.97 5.78 1.73 5977806.12 583197.29 N 70 20 57.605 W 149 19 28.420 1969.59 20.20 176.86 1926.99 324.37 -324.45 7.61 0.52 5977773.67 583199.48 N 70 20 57.286 W 1491928.367 2062.33 21.50 175.52 2013.65 357.28 -357.38 9.82 1.49 5977740.77 583202.05 N 70 20 56.962 W 1491928.303 2154.29 23.57 176.45 2098.59 392.41 -392.53 12.27 2.28 5977705.64 583204.90 N 70 20 56.616 W 1491928.231 2249.53 25.65 177.17 2185.17 431 .99 -432.13 14.47 2.21 5977666.08 583207.54 N 702056.227 W 14919 28.167 2342.35 27.49 175.68 2268.19 473.40 -473.56 17.08 2.11 5977624.68 583210.60 N 702055.819 W 1491928.090 2436.23 30.63 174.99 2350.24 518.81 -519.00 20.80 3.36 5977579.29 583214.83 N 70 20 55.373 W 14919 27.982 _./ 2530.36 33.13 174.26 2430.16 568.25 -568.49 25.47 2.69 5977529.86 583220.04 N 702054.886 W 149 1927.845 2624.68 33.18 173.85 2509.13 619.51 -619.80 30.81 0.24 5977478.62 583225.95 N 7020 54.381 W 149 1927.689 2675.82 32.88 174.25 2552.00 647.21 -647.52 33.70 0.73 5977450.93 583229.15 N 702054.109 W 1491927.605 2714.45 32.77 175.30 2584.46 668.05 -668.38 35.61 1.50 5977430.10 583231.29 N 702053.904 W 1491927.549 2806.23 32.88 177.81 2661.59 717.67 -718.03 38.59 1.49 5977380.49 583234.83 N 702053.415 W 1491927.462 2899.97 33.04 177.55 2740.25 768.61 -768.99 40.66 0.23 5977329.56 583237.46 N-7Ö 26 52.~14 W 1491927.401 2993.04 33.10 177.70 2818.24 819.33 -819.73 42.76 0.11 5977278.85 58324Ù.12 N 702052:'"415 W 1491927.340 3086.66 33.21 177.36 2896.62 870.47 -870.88 44.97 0.23 5977227.73 583242.90 N 702051.912 W 14919 27.275 3179.99 32.84 177.29 2974.87 921.25 -921.69 47.34 0.40 5977176.96 583245.84 N 70 20 51.412 W 1491927.206 3273.54 33.16 176.30 3053.33 972.10 -972.56 50.19 0.67 5977126.13 583249.2,5./ N 70 20 50.912 W 14919 27.123 " 3365.70 33.36 175.83 3130.39 1022.49 -1022.99 53.66 0.35 5977075.75 583253.28 N 702050.416 W 14919 27.021 3459.28 33.56 175.13 3208.46 1073.89 -1074.42 57.73 0.46 5977024.37 583257.92 N70 20 49.910 W 14919 26.903 3553.45 33.59 174.58 3286.92 1125.71 -1126.29 62.40 0.32 5976972.56 583263.16 N 70 20 49.400 W 149 19 26.766 3646.37 33.38 175.68 3364.42 1176.75 -1177.37 66.75 0.69 5976921.54 583268.08 N 70 20 48.898 W 1491926.639 3738.86 33.67 177.72 3441.53 1227.72 -1228.36 69.69 1.26 5976870.59 583271.58 N 70 20 48.396 W 149 1926.553 3830.95 33.87 177.92 3518.08 1278.85 -1279.51 71.64 0.25 5976819.46 583274.10 N 702047.893 W 1491926.496 ----- 3924.23 33.49 177.87 3595.70 1330.53 -1331.20 73.54 0.41 5976767.80 583276.57 N 702047.385 W 1491926.441 4017.12 34.29 177.45 3672.81 1382.26 -1382.96 75.65 0.90 5976716.08 583279.26 N 702046.876 W 1491926.379 4109.27 34.54 176.81 ~. 3748.83 1434.25 -1434.97 78.26 0.48 5976664.10 583282.45 N 70 20 46.364 W 1491926.303 4204.53 35.30 176.47 3826.94 1488.66 -1489.41 81.46 0.82 5976609.71 583286.25 N 702045.829 W 1491926.209 4298.45 35.77 175.59 3903.37 1543.08 -1543.86 85.24 0.74 5976555.31 583290.63 N 702045.293 W 1491926.099 4391.57 36.16 175.22 3978.74 1597.55 -1598.37 89.62 0.48 5976500.85 583295.62 N 702044.757 W 1491925.971 4485.64 36.05 176.46 4054.74 1652.80 -1653.66 93.64 0.79 5976445.62 583300.26 N 702044.213 W 1491925.853 4578.75 36.21 175.70 4129.94 1707.53 -1708.43 97.40 0.51 5976390.90 583304.62 N 702043.675 W 14919 25.744 4671.99 36.79 176.61 4204.89 1762.83 -1763.76 101.11 0.85 5976335.62 583308.95 N 702043.131 W 14919 25.635 L-109 ASP Final Survey.xls Page 2 of 3 6/12/2002-10:52 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/.S E/.W I DLS Northing Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 4765.18 36.55 178.83 4279.64 1818.41 -1819.36 103.33 1.45 5976280.05 583311.78 N 702042.584 W 1491925.570 4858.38 36.09 180.98 4354.74 1873.60 -1874.56 103.43 1.45 5976224.86 583312.49 N 70 20 42.041 W 149 1925.568 4951.53 35.21 181.03 4430.43 1927.89 -1928.84 102.48 0.95 5976170.58 583312.14 N 702041.507 W 14919 25.595 5044.97 33.88 184.21 4507.40 1980.82 -1981.75 100.08 2.40 5976117.65 583310.33 N 702040.987 W 1491925.665 5137.31 32.54 185.00 4584.66 2031.27 -2032.16 96.03 1.52 5976067.20 583306.84 N 70 20 40.491 W 149 19 25.784 5231.42 30.97 187.56 4664.68 2080.54 -2081.39 90.63 2.20 5976017.92 583301.99 N 702040.007 W 1491925.941 5323.24 29.34 187.14 4744.07 2126.33 -2127.13 84.73 1.79 5975972.12 583296.60 N 70 20 39.557 W 14919 26.114 5417.26 28.46 186.61 4826.38 2171.48 -2172.24 79.29 0.97 5975926.96 583291.66 N 70 20 39.113 W 149 19 26.273 5511.59 28.68 186.61 4909.23 2216.34 -2217.05 74.09 0.23 5975882.10 583286.96 N 7020 38.672 W 149 1926.425 5604.61 28.90 186.31 4990.75 2260.89 -2261.57 69.05 0.28 5975837.53 583282.42 N 70 20 38.235 W 149 1926.572 5697.50 28.99 185.78 5072.04 2305.64 -2306.27 64.32 0.29 5975792.78 583278.18 N 702037.795 W 1491926.710 --' 5790.38 29.12 186.45 5153.23 2350.53 -2351.12 59.52 0.38 5975747.89 583273.87 N 702037.354 W 1491926.851 5884.12 29.00 186.87 5235.17 2395.79 -2396.35 54.23 0.25 5975702.61 583269.10 N 702036.909 W 149 1927.005 5976.94 28.62 186.25 5316.50 2440.27 -2440.78 49.12 0.52 5975658.12 583264.48 N 70 20 36.472 W 1491927.154 6071.54 28.27 185.92 5399.68 2485.12 -2485.59 44.35 0.41 5975613.27 583260.20 N 702036.031 W 1491927.294 6164.66 28.13 185.52 5481.74 2528.94 -2529.37 39.96 0.25 5975569.44 583256.30 N 702035.601 W 1491927.422 6258.05 27.65 185.62 5564.29 2572.45 -2572.85 35.72 0.52 5975525.93 583252.54 N 70"20'35.'173 W 1491927.546 6352.31 27.42 185.83 5647.87 2615.85 -2616.21 31.37. 0.26 5975482.53 583248.68 N/70 20 34.747 W 1491927.673 6445.55 26.69 185.32 5730.91 2658.09 -2658.42 27.25 0.82 5975440.28 583245.03 N 702034.332 W 1491927.793 6538.32 26.25 185.50 5813.95 2699.29 -2699.58 23.35 0.48 5975399.08 583241.59 N 702033.927 W 1491927.907 ~- 6630.74 27.38 185.69 5896.43 2740.81 -2741.08 19.29 1.23 5975357.54 583237.Qß N 70 2e 33.519 W 1491928.026 6724.13 28.46 186.17 5978.95 2784.34 -2784.57 14.77 1.18 5975314.01. 583233.94 N 702033.091 W 149 1928.158 6816.45 29.72 186.06 6059.62 2829.01 -2829.20 9.99 1.37 5975269.33 583229.66 N 702032.652 W 1491928.298 6911.73 28.65 185.77 6142.81 2875.26 -2875.41 5.20 1.13 5975223.07 583225.38 N 70 20 32.198 W 149 1928.438 7005.69 27.44 185.95 6225.73 2919.24 -2919.36 0.69 1.29 5975179.09 583221.36 N 70 20 31.765 .W 14919 28.569 7099.12 26.08 186.43 6309.15 2961.10 -2961.18 -3.84 1.47 5975137.22 583217.30 N 70 20 31.354 W 14919 28.702 7193.15 25.05 186.29 6393.98 3001.47 -3001.50 -8.34 1.10 5975096.85 583213.25 N 70 20 30.958 W 1491928.833 .~ 7286.15 24.39 186.28 6478.45 3040.16 -3040.16 -12.60 0.71 5975058.15 583209.42 N 702030.577 W 1491928.957 7380.44 23.43 185.66 6564.65 3078.20 -3078.17 -16.58 1.05 5975020.11 583205.86 N 702030.204 W 1491929.074 7474.40 22.65 185.50 ~ 6651 .12 3114.83 -3114.77 -20.15 0.83 5974983.47 583202.69 N 702029.844 W 14919 29.178 7566.14 22.65 182.85 6735.78 3150.07 -3149.99 -22.72 1.11 5974948.22 583200.51 N 70 20 29.497 W 149 19 29.253 7658.52 22.93 182.21 6820.95 3185.83 -3185.74 -24.30 0.40 5974912.46 583199.33 N 702029.146 W 149 1929.299 7735.15 22.34 183.28 6891.68 3215.30 -3215.20 -25.71 0.94 5974883.00 583198.25 N 702028.856 W 14919 29.341 7820.00 22.34 183.28 6970.16 3247.52 -3247.40 -27.56 0.00 5974850.78 583196.76 N 70 20 28.539 W 1491929.394 L-109 ASP Final Survey.xls Page 3 of 3 6/12/2002-10:52 AM .--.. ........ Q)...-... Q) -.J -(J) 8~ 0 Q) ~ > II B c ro :;:~ ,-,,0 .J:::. ~ ........ c.o CLI'-- Q).........- orn -~ ro " U 4- .- Q) ta:: Q) > > Q) ~ ::J W ~ bp 0- 1000 2000 ~... ...- ,--, ....... ...- ') ) Client: Well : VERTICAL SECTION VIEW BP Exploration Alaska L-109 Field: Prudhoe Bay Unit - WOA Structure: L-pad Section At: 180.49 deg Date: ""., June 12, 2002 Q ..- ._n -. --.. -. --. --- ._-. ~_. .-.. ,.n., -..., -- ...- -. -'- ...- .-.. -. -- _n ,-~. ._~ .- ...- -,- -- .y- - _. - -' - -.. - - --'----- 6000 - -.----.- 7000 - - -- - -- .... "0" ..... ...., ".... .-.. -... -.-.- ,"" ._u -.- .-- .-- _-A ,-- h_' .-- _00' __A __A -.- .~ -- -- .- ..... ,,-. -- .-. .u- - - --. m., -- .- --- -~ Schlumberger ,j. - - - - I 4000 Vertical Section Departure at 180.49 deg from (0.0, 0.0). (1 in = 1000 feet) -----.- -------_.- ..-. . .... ..... - - - - ... -,.- ..... .1.. .... ....' ... . ------ -..---.-. ,.. ...oO U- ..... n ------. I 0 I 1000 ,- .. ... 'h. .-. - - - I 2000 I 3000 ) ) bp .....~ \" .. .'. 'øt~; PLAN VIEW Client: ' Well: Field: Structure: Scale: BP Exploration Alaska L-l09 Prudhoe Bay Unit - WOA L-Pad 1 in '" 500 ft Schlumberger Date: 12.,Jun-2002 \ -1 000 -500 I " 0 500 I 1000 \ '-, 0-.... True North Mag Dee ( 0 -500 0 --500 h. ^ -1000 -1000 ^ ^ I I- a:: 0 z -1500 --1500 I I- ::> 0 (f) V V V --2000 () ,J -2500 - --2500 r--"'C'-'i --3000 -3000 - L-1 09 ¡ i ¡ I I I rJ) ..1.;: ¡ L-109 (P7) .J ~¡ i (: -3500 - I -1 000 I -500 «< WEST --3500 I 0 500 EAST »> 1000 Scblulllbepgep Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ~- Well Job# L-109 aOl-anl L-110 ~()J- J~ ~ Log Description SBHP PRODUCTION LOG 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 AK 99508-4254 Date Delivered: RECEIVED AUG 0 9 2002 Alaska Oil & Gas ConS. Commision Anchoraae Date 07/17/02 07/23/02 NO. 2283 Company: Alaska Oil & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Color Sepia BL CD Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth Receivea-~OopvJ 8/6/2002 '_/ ~~ Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well .<1nsd.oJ L-109 L-109 L-109 L-109 L-109 L-109 L-109 V L-108 dC\d- 10'1 V-102 ~l')~ - O~ ~ V-102 \ V-102 ...þ Job# Log Description 08/07/02 NO. 2300 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Date Color Sepia BL CD 06/06/02 06/06/02 1 06/06/02 1 06/06/02 1 06/06/02 1 06/06/02 1 06/06/02 1 08/03/02 1 OS/21/02 OS/21/02 1 OS/21/02 1 .~ 22303 PEX-AIT -BHC-POROSITY 22303 PEX-AIT 22303 PEX-BHC 22303 PEX-POROSITY 22303 PEX- TRIPLE COMBO 22303 PEX- TRIPLE COMBO SSTVD 22303 PEX-HOLE & CEMENT VOLUME LEAK DETECTION LOG 22258 OH MWD/GR 22258 MD IMPULSE-GR 22258 TVD IMPULSE-GR ~J 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 AK 99508-4254 Date Delivered: RECEIVED t~UG 0 9 2002 AlaSkaOiJ & Gas Cons. Cœnmision J\n~ Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TIN: Beth Received~ «~ 7/25/2002 Schlumbergep NO. 2261 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Well Job # Log Description Date Color Sepia BL L-110 aOJ- I ~ ~ PRODUCTION PROFILE 07/13/02 1 L-1 08 ~O~ - J l'leJ¡ 22318 USIT 06/30/02 2 L-109 C) 1- ~ l'¡} 22304 MWD GR 06/06/02 L-1 09 -1 22304 MWD GR MD 06/06/02 1 L-1 09 22304 MWD GR TVD 06/06/02 1 CD .~ 1 -- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Date Delivered: AJaska O¡.¡ & Gas Cons. CJmmi35icn ¡\nene-rage Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Receive~ ~.,~ BP Exploration (Alaska) Inc. .... '" --- . . Petrotectnical Data CentefQ.~C F ! \1 ~- 0 900 E Benson Blvd. ~ '\;;.;.nc -- - II .' ..-. Anchorage AK 99508-4254 Ii II I") f-. ?(';;'!? uvL Lv ;...\01"- SC_.~8Pg8P Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth ,-;~ Well Job# L-109 ~QI-aOJ l-109 l-109 L-109 L-109 L-109 l-109 Log Description 22271 PEX AIT BHC DATA (PDC) 22271 PEX AIT 22271 PEX DEN/NEUTRON 22271 BHC 22271 PEX TRIPLE COMBO 22271 PEX SSTVD 22271 PEX HCAl-CALlPER lOG v 5-107 ~Ol- JJ..~ ,--.. R5T WFl 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 AK 99508-4254 Date Delivered: RECEIVED III ~'o! 2 .c' IJOO?" \.JVI. . L - Nask: Oil& GesCons. ComI11Bsion Anchorage Date 06/01/02 06/01/02 06/01/02 06/01/02 06/01/02 06/01/02 06/01/02 06/14/02 6/19/2002 NO. 2179 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora Color BL CD Sepia Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherríe ReceIV~(~ ~ ) ,\t~t,. bp ~~~ ~~. ~.- -~. "~,.IÅ"'~. .'J'It\." ) ~o I ~ ¿t7 \ To: Winton Aubert, AOGCC Date: June 17, 2002 From: Neil Magee Remedial Cementation on L-I09 (Nabors Rit! 9ES) Subject: Remedial cement work performed on well L-I09i to isolate the Schrader formation was performed as per my earlier e-mail of 6/12/02. A description of operations follows: A 34 bbl circulationlblock squeeze was performed on the Schrader interval which resulted in circulating 15 bbls of cement through the Schrader perforations upward as indicated by the flow ITom the 7" x 9-5/8" annulus valve, followed by a 10 block squeeze on the Schrader perforations to a final pressure of 1020 psi. Following a WOC time of 12 hours, a 20 bbls cement down-squeeze was performed on the 7" x 9-5/8" annulus placing cement below the 9-5/8" surface casing from 2950' to 3550'. After cleaning out the two squeeze retainers, a USIT was run which indicated significant improvement in the quality of cement across the Schrader perforation interval with adequate isolation above and below. Subsequent injection into the Schrader perforations whilst pressuring up the 7" annulus to fire TCP guns, revealed that the annular communication to the 7" x 9-5/8" had been corrected. The well was subsequently completed as a dual inj ector per the approved 401. -/ Attached is a wellbore schematic detailing the final cement intervals. Sincerely, Neil Magee BP Drilling Engineer 564-5119 L L L TD = 7,820' ') L-I09i Cement Detail ~ 20" Casing ~ 9-5/8" Casing Top Squeeze: 20 - bbls 15.7 Articset I cement from 2950' to 3550' Schrader cemented from 5420' to 4100' - § Schrader = Perforations - . ... ES Cementer @ 5420' Kuparuk Cemented 7808' to 500' above at 7000' ~ 7" Casing SIZE 20" 9-5/8" 7" WT 91.5 40 26 ) CASING DETAIL GRADE CONN H -40 Welded L-80 Buttress L-80 Buttress SCHRADER PERFORATION DATA Zone OA OBa OBd OBc OBd OBe Interval 4764-4794' 4844-4880' 4894-4910' 4962-4985 ' 5024-5065 ' 5096-5108 ' Date 6/10/02 6/10/02 6/1 0/02 6/10/02 6/10/02 6/10/02 DEPTH Surf 2,719' 7,808' ) ) MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No L-109i Date Dispatched: 11-Jun-02 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys dO' .:.aO] 2 Received BY:~ (J) 00 p:J RECEIVED Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 II I ~, 1 ~ 2002 ..;v¡ ~ L-r Alaska Oil & Gas Cons. Commission Anchorage ) ~~~11. bp ~~~ ~~. .-..~ -F"''' .'_'~\" ) To: Winton Aubert, AOGCC Date: June 12, 2002 From: Neil Magee Remedial Cementation on L-I09 (Nabors Rig 9ES) Subject: We will be performing remedial cement work on well L-l 09i which is outside the scope of work detailed in the approved 401 Permit to Drill. Below is a summary of the events which led up to the change in scope. The 7" long string on this well was cemented in two stages via an ES cementer with 15.8 ppg cement. The USIT log indicated excellent cement though the Kuparuk interval however marginal isolation across the Schrader interval. A second USIT log was run some 18 hours later with marginally better readings across the Schrader. After conferring with Schlumberger here in Anchorage it was decided that the Schrader isolation was sufficient to proceed on with the completion phase. The well was TCP perforated in the Schrader interval and subsequently cleaned out in preparation for running the completion string. While running the completion string the 7" x 9-5/8" annulus was being freeze protected with dead crude. Just as that job was nearing completion the rig crew noted returns in the 7" casing and the well was shut in and observed. The pressure readings on the 7" x 9-5/8" annulus and inside the 7" indicated that a U-tube situation with trapped pressure was present. Both the outer annulus 7" x tubing annulus was subsequently bled of indicating that the well was in a safe condition. During the bleed of there was direct communication apparent between the 7" casing perforations in the Schrader, and the outer annulus indicating that the upper Schrader was not cement isolated. Subsequently the completion was pulled from the well ahead of remedial cement operations. As per my e-mail of 6/12/02, BP plans on performing a circulation/block squeeze above and through the Schrader interval to a depth of approximately 3500' some 800' above the top perforation interval. After this an USIT log will be run the verify integrity. If cement integrity can be verified, the well will be completed as originally planned. I will keep you informed if any further changes to the well program are made and will provide a Sundry 403 notice as requested. Sincerely, Neil Magee BP Drilling Engineer 564-5119 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. ) L-I09i Remedial Cement Plan PU wear bushing. RIH picking up pipe to 6000' or enough to make full trip to 7723' (Baffle) on next clean out run. Circulate well clean with completion brine. No need to clean up returns at this point. POOH and stand back. RU Schlumberger and RIH with EZSV/FastDrill's. Set lower EZSV at 5150' GR/CCL. The upper FastDrill can be set at 4710' GR/CCL. Pressure test casing above EZSV to 3000 psi- No outer annulus pressure. RIH with star-guide stinger and break circulation prior to stinging in. Sting in and establish injection/circulation rate at +/-2bbl/min while holding annulus valve open. (See note below.) Note: T'X 9-5/8" should be bled into suitable tank holding approximately 150 psi back pressure until mud returns are noted. It's anticipated that 40+ bbls of dead crude after which 10.1 ppg mud will be recovered. Pump 15 bbls CW-I00 followed by 34 bbls (170 sks) 15.8 ppg cement to 3550' assuming no excess, 3848' assuming 30% wash-out with annulus valve in full open position. The last 10 bbls pumped should be "hesitated" with annulus valve in closed position. Displace with cement with 9.1 ppg brine. Note: Check annulus clear of cement after 5 hours (to be verified) by pumping 2-3 bbl every hour. POOH of EZSV and circulate drillpipe clean. POOH. PU clean out assembly and RIH to top EZSV. WOC until 500 psi compressive strength. Displace 9-5/8" x 7" annulus to 9.1 ppg mud monitoring returns inside 7" casing. If no returns are noted inside 7" casing, continue to freeze protect with dead crude to 2200'TVD. If returns are noted prepare for top job on annulus with 15.8 ppg cement. Drill out EZSV's with hi-vis sweeps to carry out debris and RIH to bottom. Displace well to clean 9.1 ppg KCL brine. POOH and RU Schlumberger to run USIT Run USIT from 200' below Schrader to surface casing shoe. E-mail results into town and contact Neil Magee and Bruce Smith (h-345-2948, w-564-5093). The Asset will make a final decision as to re-shooting Schrader. ') ) 13. RU and run Halliburton to re-shoot Schrader interval. 14. RD Halliburton and make clean out trip to TD remove perf debris 15. Circulate well clean and POOH and lay down excess drill-pipe. Pull wear bushing. 16. Run completion. ) ~~~7E C)~ i%~fÆ~[~fÆ / I AltASIiA. OIL AIQ) GAS I CONSERVATION COMMISSION / TONY KNOWLES, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit L-1 09i BP Exploration (Alaska) Inc Permit No: 201-201 Sur. Loc. 2376' NSL, 3728' WEL, SEC 34, T12N, RIlE UM Btmhole Loc. 1113' SNL, 3594' WEL, SEC 03, T11N, RIlE, UM Dear Mr. Crane, Enclosed is the approved application for permit to drill the above referenced well. Operation of this well in enhanced recovery service is not approved until the Area Injection Order has been issued. The permit to drill 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. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit L-109i. A diverter waiver has been requested for Well L-1 09i for drilling the shallow section to a depth of approximately -2570' TVDss. The L-Pad in the western portion of the Prudhoe Bay Unit is located over a thick accumulation of sub-permafrost methane hydrates that are underlain by a significant accumulation of free hydrocarbon gas. The shallow section in the well would include the interval containing the methane hydrates, but not the underlying free gas accumulation. At least fourteen wells have been drilled from L-Pad, which demonstrates the shallow section can be successfully drilled without a diverter by using specialized mud treatments and drilling procedures. Therefore, the diverter waiver for well PBU L-1 09i is approved provided BPXA: 1) employs a high-resolution, early kick detection system in addition to the other hydrate mitigation procedures described in the permit to drill application for the subject well; and 2) obtains an additional surface hole log suite in Well L-109i consisting of Gamma Ray, SP, Resistivity, Neutron-Density, Sonic, and calibrated gas logs. Well L-109i is the most appropriate well in the current L-Pad drilling schedule for obtaining additional control. ) Permit No. 201-201 May 21, 2002 Page 2 of2 Commission approval of the diverter waiver for PBU L-109i does not guarantee approval of future diverter waiver requests on this or any other drill site. Diverter waiver applications will continue to be cæ:efully considered on a case-by-case basis. Enclosed is the approved applicatiòn for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a cons.ervation order approving a spacing exception. BP Exploration (Alaska), Inc. will assume the liability of any protest to the spacing exception that may occur. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC25.035; 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 performed before drilling below the surface casing shoe, 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, (nMO U ,C4W.'.l~-/ 't"~~chsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 21st day of May, 20,02 jjc/Enclosures cc: Department ofFish &' Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA STATE OF ALASKA '1 AND GAS CONSERVATION COM~. PERMIT TO DRILL 20 AAC 25.005 '))ION ¡ y.M. 3/IBlO 1- k ~ {;2. Ct.~0 ":L .'" 1 a. Type of work III Drill 0 Redri\l 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519.6612 4. Location of well at surface 2376' NSL, 3728' WEL, SEC. 34, T12N, R11 E, UM At top of productive interval 783' SNL, 3607' WEL, SEC. 03, T11 N, R11 E, UM At total depth 1113' SNL, 3594' WEL, SEC. 03, T11N, R11E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028239, 1113' MD NWE 1-02 is 235' away at 500' MD 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications $12.,e Casina Weiaht Grade Couplina 20" 91.5# H.40 Weld 9-5/8" 40# L.80 BTC 7" 26# L.80 BTC-M Lenath 80' 2678' 8485' 0 Exploratory 0 Stratigraphic Test QDevelopment Oil III Service 0 Development Gas 0 Single Zone (jZI ~ltjpJe Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB :::: 76.2' Prudhoe Bay Field / Borealis 6. P~erty Designation Pool (Undefined) ð1-l:.2" Jþ; AD~Q28241 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number L -1 09i 9. Approximate spud date 10/25/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8158' MD /7204' TVD 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 31 Maximum surface 2750 psig, At total depth (TVD) 6538' 13403 psig Setting Depth TQD Bo~om MD TVD MD TVD Surface Surface 110' 110' Surface Surface 2706' 2576' Surface Surface 8158' 7204' 11. Type Bond (See 20 AAC 25.025) 1 b. Type of well Number 2S100302630-277 Hole 30" 12-1/4" 8-3/4" QI,J~.nljtv of Cement (include staae data) ¡260 sx Arctic Set (Approx.) , 365 sx Arcticset Lite, 240 sx 'G' 251 sx LiteCrete, 281 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED OCT 1 0 Z001 true vertical Araska Oil & Gas Cons. Commission Anchorage Perforation depth: measured 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Neil Mage , 564-5119 Prepared By NamelNumber: Terrie Hubble, 564-4628 21, I hereby certifv that the foregoin is true a~d rr ct to the best of my knowledge L.00..ù.(..(\ C-ra 1\0(.. Signed ~ ~. '~7 ~ Title Senior Drilling Engineer Date /0-- 5'- Ð 1 ::::i~~~:-:~~~~amp:~~;!;- ~ 30 sI¿:;:~:~Mudj~~r~t? ~ ~~~E~~~~~ments Hydrogen Sulfide Measures 0 Yes 00 No Directional Survey Required 5(J Yes 0 No Required Working Pressure for BOPE 0 2K. 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: -rest- þopE to 40'l)(j f sA . V\\\~<:.2""-~"-~~\-\'-l~"> ,- ". by order of," Jí Approved By Ongin~~~~:;(X Commissioner the commission Date') !..:J/ {:';2-- Form 10-401 Rev. 12-01-85 \C'dI1l11\Y 0 \ Gl \,~ Submit In Triplicate 20. Attachments ) ) I Well Name: IL-109i Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Injector Surface Location: As-Built Target Location: Top Kuparuk Bottom Hole Location: x = 583,188.27' Y = 5,978,097.98' 23761 FSL (29031 FNL), 37281 FEL (15511 FWL), Sec. 34, T12N, R11 E X = 583,350.08' Y = 5,974,940' 44961 FSL (7831 FNL), 36071 FEL (16721 FWL), Sec. 03, T11N, R11E X = 583,366.98' Y = 5,974,609.62' 41651 FSL (11131 FNL), 3594' FEL (16841 FWL), Sec. 03, T11N, R11E 1 AFE Number: 15M4021 I Estimated Start Date: 11 I RiQ: 1 Nabors 9ES I OperatinQ days to complete: 113.1 1 MD: 18158' 1 TVD: 17204' I BF/MS: 126.9' I 1 RKB: 176.2' I Well DesiQn (conventional, slimhole, etc.): 1 Ultra Slim hole (Iongstring) 1 Objective: I Schrader/Kuparuk Formation Mud Program: 12 "fA" Surface Hole (0-2706'): Densitv (ppg) 8.5 - 8.6 9.0 - 9.5 9.6 max Initial below Permafrost interval TD Viscosity (seconds) 300 200-250 200-250 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/1 OOft~) (mls/30min) 50 - 70 15 - 20 50 - 70 < 10 50 - 60 < 1 0 8.5- 9.5 8,5 - 9.5 8.5 - 9.5 8 3A" Intermediate I Production Hole (2706' - 8158'): Undecided Interval Density Tau 0 YP PV pH API HTHP (ppg) Filtrate Filtrate Upper 9.3-9.6 4-7 20-25 8-12 8.5-9.5 4-6 Interval Top of HRZ 10,3 5-8 20-25 8-14 8.5-9.5 3-5 <10 by to TD HRZ Hydraulics: Surface Hole: 12-1/4" Interval Pump Drill A V GPM Pipe (fpm) 0-2,000 500 4" 17.5# 90 2,000'-2,706' 600 4" 17.5# 110 Intermediate/Production Hole: 8 3,4" Pump PSI 1500 2170 ECD ppg-emw 10.2 10.2 Motor Jet Nozzles ("/32) N/A N/A TFA (in2) 18,18,18,13 .875 18,18,18,13 ,875 L -1 09i Drilling Program Page 1 ) Interval Pump Drill Pipe GPM 2706' - 8158' 575 4" 17.5# Directional: Ver. Anadrill P3 Slot SK KOP: 300' Maximum Hole Angle: Close Approach Wells: AV (fpm) 200 Pump PSI ) 3200 ECD ppg-emw 11.3 6x15 Motor Jet Nozzles ("/32) N/A TFA (in2) 1.03 310 at 2304' MD All wells pass major risk criteria. NWE 1-01 - 282' @ 300' MD NWE 1-02 - 235' @ 500' MD L01 -72' @ 500' MD L-110 - 47' @ 500' MD L-116 -15' @ 500' MD L-114 -118' @ 800' MD L-107 - 88' @ 700' MD L-115 -75' @ 600' MD IFR-MS corrected surveys will be used for survey validation. GyroData will be needed for surlace hole close approaches. LOQQinQ PrOQram: Surface Intermediate/Production Hole Formation Markers: Formation Tops MDbkb SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma Na Oa Obf Base CM2 (Colville) THRZ BHRZ (Kalubik) L-109i Drilling Program Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Den / Neut Open Hole: MDT (Contingency) Cased Hole: US IT cement evaluation TVDss 1465 1610' 1775' 1950' 2120' 2440' 2780' 3120' 3579' 3841' 4090' 4260' 4652' 5025' 6230' 6410' Estimated pore pressure, PPG Hydrocarbon bearing 2000 psi, 9.2 ppg EMW Hydrocarbon bearing Page 2 ) ) K-1 TKUP Kuparuk C LCU (Kuparuk B) Kuparuk A TMLV {Miluveach} TD Criteria 6480' 6538' 6557' Hydrocarbon Bearing, 3403 psi, 10.0 ppg EMW 7000' 8158' 150' below Miluveach top CasinglTubin~ Program: Hole Csgl WtlFt Grade Conn Length Top Btm Size TbQ O.D. MDrrVD MDrrVD bkb 30" 20" 91.5# H-40 WLD 80' GL 11 0/11 0 12 %" 9 5/8" 40# L-80 BTC ~ GL 2706' 2576' -485' ~ ~ 8 3,4" 7" 26# L-80 BTC-m GL ..f8158i 204' Tubing 3 Y2" 9.2# L-80 NSCT 0' Tubing 4 Y2" 12.6# L-80 NSCT 7789' GL 7313'/6486' Integrity Testing: Test Point Depth Surface Casing Shoe 20' min from surface shoe Test Type LOT EMW 13.0 ppg EMW Target Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casinq Size 19-5/8" Surface I Basis: Lead: Based on 1882' of annulus in the permafrost @ 2500/0 excess and 218' of open hole from top of tail slurry to base permafrost @ 300/0 excess. Lead TOC: To surface/'.' Tail: Based on 606' MD open hole volume + 300/0 excess + 80' shoe track volume. Tail TOG: At -2100' MD ;/ Total Cement Volume: Lead 288 bbl / 1615fe / 365 sks of Dowell ARTICSET Lite at 10.7 ppg and 4.44 cf/sk. Tail 50 bbl / 280 fe / 240 sks of Dowell Premium 'G' at 15.8 ppg and 1 .17 cf/sk. Casinq Size 17" Production Longstring I Basis: Lead: Based on TOC 1000' ab°':7 top of Schrader formation + 300/0 excess Lead TOC: estimated 3285' MD Tail: Based on 1687' MD of open ~Ie +30% excess + 80' shoe track volume Tail TOC: estimated at 6463' MD Total Cement Volume: Lead 83 bbls / 600 fe /251 sks of Dowell LiteCrete at 12.0 ppg and 2.39 cf/sk. L-109i Drilling Program Page 3 ) Tail 59 bbls /330 fe / 281 sks of Dowell Premium "G" at 15.8 ppg and 1 .17 ctlsk ). . (,>'\~~~<rx~~\()"-~,,~~. ~Ct~\>(~";) ~:~ Well Control: , çefNxr.,\ft.~\ Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 4000 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: 3403 psi @ 6538' TVDss - Kuparuk Sands . Maximum surface pressure: 2750 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: 4000 psi (The casing and tubing will be tested to 4000 psi.) . Planned completion fluid: 9.2 ppg filtered brine / 6.8 ppg diesel L-Pad well have proven kick tolerances in the 25-55 bbl range. A heightened awareness of kick detection and pre-job planning will be essential while drilling/tripping in the productive intervals. Disposal: . No annular disposal in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. L-109i Drilling Program Page 4 ) ') DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is in place. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and 1 or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig Operations: -, "'92:~ ~~~~~ ~ ~(þ~\ \ (( ~ r 1. MIRU Nabors 9ES on Slot SK. 2. Nipple up diverter spool and riser. A diverter waiver has been applied for. PU 4" DP as required and stand back in derrick. 3. MU 12 %" drilling assembly with MWD/GR and directionally drill surface hole to approximately 2706' MD 1 2576' TVD. An intermediate wiper/bit trip to surface for a will be performed prior to exiting the Permafrost. The actual surface hole TD will be +1-100' TVD below the top of the SV1 sand. 4. Run and cement the 9-5/8", 40# surface casing back to surface. A Tam port collar will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. ./ 5. ND diverter spool and NU casing 1 tubing head. NU BOPE and test to 4000 psi. 6. MU 8-3/4" drill!pg assembly with MWD/GR/RES/DEN/NEU and RIH to float collar. Test the 9-5/8" casing to 4000 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.3 ppg drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill ahead and increase mud weight to 9.6 ppg prior to entering the Schrader Oa sand, 9. Drill to +1-100' above the HRZ, ensure mud is in condition to 10.3 ppg and perform short trip as needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 10. Drill ahead to -150' of rat hole into the Miluveach formation, Condition hole for running 7" 26# long- string. 11. Run and cement the 7" production casing as required from TD to 1000' above the Schrader Bluff if indicated oil bearing otherwise 1000' above uppermost oil bearing reservoir. Displace the casing with seawater during cementing operations and freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdo)Yn pressure on Morning Report. 12. Test the casing to 4000 psi for 30 rl)k1utes. 13. RU Schlumberger and run USIT log on e-line from the 7" float collar to TOC. Be prepared to immediately run a temperature log sfì'ould the cementing of the production casing be suspect. 14. Test the casing to 4000 psi for 30 min. 15. Perforate Schrader interval on e-line. 16. Make scraper run and POOH laying down excess drill-pipe. / 17. Run the combination 3-1/2" 9.3#, L-80 NSCT 1 4-1/2", 12.6#, L-80 NSCT completion assembly, Set packers and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes. Shear RP valve and install TWC. Test below to 2750 psi. 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 19. Freeze protect the well to -2200' TVD. Allow diesel to U-tube from the annulus to tubing and equalize at 2000' TVD. 20. Rig down and move off. Estimated Spud Date: 10-25-2001 L-109i Drilling Program Page 5 ) ') L-109 Hazards and Contingencies Job 1: MIRU Hazards and Contingencies ~ L-Pad is not designated as an H2S site. NWE1-01 and NEW 1-02 did not report H2S as being present. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. » The closest surface location is L-116i, 15 feet to the west. No surface shut-in's will be required as this well will not be on production. ~ Due to the elevated landing ring height on L-Pad, the BOP stack will need to be run with a l' double flange adapter spool on bottom (13-5/8" x11") Reference RPs Operational Specifics _:;:'~lllt~.:.:... .::.:.7;;;I;.;r,,^....1~ Job 2: DrillinQ Surface Hole ~ No faults are expected to be penetrated by L-109 in the surface interval. ~ There are two close approach issues in the surface hole. All wells pass major risk criteria. The closest existing well, L-116 is 15' center-center at surface to -500' MD. Well L-110 will cross 47' center-center distance at -500' MD. A GyroData survey will be utilized while drilling the surface hole until clear of maç¡nAt,Ï.G int~ref&:mce. '- ~ Gas hydrates have been observed all wells drilled on L-Pad. These were encountered near the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation » Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) ~ Reference RPs Operational Specifics : '-IIIII;:-'-III-:-:-'--:'"I'I:m:'-I-"IIIIII;IIIIII;:1111II11".'111..1 ... """""'¡N¡!' I I Job 3: Install surface CasinQ Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity, 2500/0 excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 9-5/8" port collar will be positioned at:t1 OOO'MD to allow a secondary circulation as required. ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2, Cement - Top of tail >500' TVD above shoe using 30% excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. Reference RPs L-109i Drilling Program Page 6 ') ") OperaNonalSpecifics Job 7: DrillinQ Production Hole Hazards and Contingencies > No losses are expected to be crossed in the production interval. If mud losses are experienced, consult the Lost Circulation Decision Tree regarding LCM treatments and procedures, > KICK TOLERANCE: The reservoir pressure of the Kuparuk has been determined to be 10.01 ppg. In the worst case scenario of 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.4 ppg at the surface casing shoe, 10.5 ppg mud in the hole the kick tolerance is 25 bbls. LOT's of 13.5ppg (L-01), 15.4ppg (L-116), 15.6 ppg (L-114), 13.7ppg (L- 110), 13.8ppg (L-107) and 13.0ppg in (L-117) have been recorded in offset L-Pad wells. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 12.4 ppg. > L-Pad development may have "kick tolerances" in the 25 bbl range or less. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals ~ There are no "close approach" issues with the production hole interval of L-115i. ~ A 4% KCL polymer mud system will be used in the production interval. Experience suggests that wiper trips will be required more frequently in the SV and Ugnu - each 1000' of hole in the SV and Ugnu. Subsequent wiper trip through these intervals will be required on an alternating day basis to stabilize these intervals. Flow rates should be maintained in the 575 gpm range particularily while drilling with higher ROP's (300'/hr) through the SV and Ugnu intervals. Baroid will prepare hydraulic and hole cleaning models for these hole intervals prior to spud. Reference RPs Operational Specifics ~III ~ -1,1:111: III: III!!: 11111.111: I: :IIC I ItW~I¡lmmrml',:II:rlrl:I,~I:Wllllllc-,IL-:~'llm,"I,:II+::llllrl:IIIII__I_,-:I:I:-c:mll~r:::--_11Im,U!III:II:II:111111:IIC,I::I:II_II_L:__--:.:~:::::>U:',lmll,:,ln,I:IUI:111,11_1_I_L_::III<C,IIIIU~r!:lr,:II:IaI,:I'II,lrll,:_III__11I1::I::--~I-:llrl:I:llrC,III:II!III,:II¡m:mll.!:::!I::¡:I.--JffiI.:::::";"',..NUoIm-'..'" Job 9: Case & Cement Production Hole Hazards and Contingencies > The Ugnu 4A is not expected to be oil bearing. For this reason the 7" casing will be cemented to 1000' above the Schrader sand if logs indicate that it is oil bearing otherwise the cement will be brought up to 1000' above the Kuparuk. The top of the hydrocarbon interval should be verified with LWD resistivity log. > Ensure the production cement has reached a compressive strength of 500 psi prior to freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with 56 bbls of dead crude (2000'), the hydrostatic pressure will be 10.1 ppg vs the 10.0 ppg EMW of the formation pressure. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours, Trapped annulus pressure may be present after pumping the dead crude however the hydrostatic pressure of the mud and diesel should exert a 46 psi overbalance to the open hole. (A second LOT will be required prior to displacing freeze protect. This to satisfy /' AOGCC for future annular pumping permits.) ~ A cement bond log (USIT) will be run to confirm the TOC. This will be done with the rig prior to perforating and running the completion. L-109i Drilling Program Page 7 ) ) ~ If the cement job is suspect be immediately prepared to run a temperature log following the cement job to verify TOC. ~ The well will be over-balanced after displacing the cement with 9.6 ppg brine. Verify that the floats are holding before continuing operations and hold pressure on the well if they are not holding. ~ Ensure a minimum hydrostatic equivalent of 10.3 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes Reference RPs Operational Specifics m;m;;mm.-¡,;;;;,-mm;¡m.:;¡¡mÞm!j.;;;;~!;;;¡;mmm;;¡¡mm m ~;;}$;;;;¡'Ì'i';;;;ffm#M#mmJ!!^-mm;¡¡¡;mmmm; ,j.*,»",.,)y,.»-mmmm¡,;;;.;;;;....:¡"w¡;,I..J;;;;.;;;;m;¡m¡m;';;;~J;mwm¡¡m..~¡¡m¡m¡;;...;;.'j.w,1'I"""'m'1'mm~';;':;;;~.-,I¡'-,-¡!¡¡;,-¡mmm. Job 1 0: Perforate Well Hazards and Contingencies ~ The well will be perforated with 9.2 ppg brine across a 8.8 ppg EMW reservoir for an overbalance of 90 psi. Be prepared for losses upon firing guns. Do not allow fluid level to drop below the BOP stack as a lower fluid level may induce a well control situation. Ensure all responsibilities are clearly communicated with to fluid handling/monitoring. Watch hole fill closely while POH with TCP guns. ~ Prior to the first gun being brought to surface, conduct a safety meeting reviewing the trapped gas possibility especially when breaking out the gun blank. All non essential hands should stay clear of the cellar once the guns reach 100' until all guns are out of the hole. Reference RPs Operational Specifics ~:"»:~IOWI¡""u'-""'."'......_--"X""''-'''''_:;=I'''''''W/''''''N~'''',m-~..: '..._---"";"""':':'';.I''''''''''''''''''-''''-'-:=:=::~iIICil:I':*,»I-M~H;::::¡::;~~=;.m. 11:'III'IIIIIIWII,::lllnm: .'~lalmI~~OHI¡lmIOI:IU:IWI .....:"';1-- -II~-' 'T-T -:I;UII----'-- --I Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The Schrader interval of the well will be perforated. Reference RPs Operational Specifics Job 13: ND/NU/Release Ria Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics L-109i Drilling Program Page 8 ) ) Proposed L-109 Completion TREE: 4-1/16" - 5M CIW Carbon WELLHEAD: 11" - 5M FMC G5 Cellar Elevation = 48.6' RKB-MSL = 77.1' I . 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 2150' I 9-5/8",40 #/ft, L-80, BTC ~ ~ 2706' Gas Lift Mandrels with handling pups installed. -'-""-"'-'._'---'-'---'----"'-""---"~-'-"--"--------..--.---.-------------..-..--....-.,-'''---.------"------'----'-"'-"-- L # MD GAS LIFT MANDRELS -----.....-,-..---- --.,.----."...-..--- .----... -.-.-----.--.--- Type Valve Type .---_."..,-- ..---.--.--.----.--...-...-,-.-,...--- .--..-..------.---- '--'-"-------'---"--"-'---"-------"-------'-"'-'-"-------.,----,.,,-.".-..-. 1 2 3 4 3-1/2" MMGW 3-1/2" MMGW 4-1/2" KBG-2 4-1/2" KBG-2 Dummy Dummy Dummy RP L .-----,.--""-..-.,-..---.----.-.------.-.-...---.......--.-..----.---.-.,---.,-...---.---. '-'R' '"-"u.~.. ..~..._w~._.,,---,.,_._._--,.,-,. -_.,-,~-,.._- ~ 4-112" 12.6# L430. Premium Connection Tubing 4-1/2" 'X' Landing Nipple with 3.813" . II ~ seal bore ø 7" x 4-1/2" Baker "Premium" ~ Production Packer with anchor 200' above Schrader productive interval 3-1/2" MMGW Water Flood GLM --------!: with Injection Valve with New Vam BxP ~- L 3-1/2" NSCT 9.3 # L-80 Tubing between MMGW GLM's Schrader Perforations: ??? ,r 3-1/2" 'X' Landing Nipple with 2.813" seal bore 7" x 4-1/2" Baker "S-3" Packer 3-1/2" 'X' Landing Nipple with 2.813" seal bore 3-1/2" 'X' Landing Nipple with 2.813" seal bore 3-1/2" WireLine Entry Guide set at 150' above Kuparuk Plug Back Depth 8058' 7",26 lIft, L-80, BTC-Mod 81581 Date 10-08-01 Rev By NM Comments Borealis WELL: L-109 API NO: 50-?? Proposed Completion (P3) BP Alaska Drilling & Wells Report Date: July 19, 2001 Client: Alaska Drilling & Wells Reid: Prudhoe Bay Unit - WOA dy Structure I Slot: l-PAD/l-109 b81-'" Stu Well: l-109 51- I I.~ Borehole: l-109 Fea UWUAPII: 50029 SulVey Name / Date: l-109 (P3) I July 19, 2001 Tort I AHD I DDII ERD ratio: 31.925° /3529.59 ft /5.106/ 0.49C Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Location LltlLong: N 70 21 0.477, W 149 19 28.58~ Location Grid HIE Y/X: N 5978097.980 ftUS, E 583188.270 ftUS Grid Convergence Angle: +0.63606380° Grid Scale Factor: 0.99990786 ~ I KBE KOP 1/100 StatIon ID Bid 1.5/100 SV5 SV4 L-109 (P3) report. xis L-109 Ichlumberger Proposed Well Profile - Geodetic Report Survey I DLS Computation Method: Minimum Curvature Ilubinski Vertical Section Azimuth: 177.700° Vertical Section Origin: N 0.000 ft, E 0.000 fI TW Reference Datum: KB TW Reference Elevation: 76.4 ft relative to MSl Magnetic DeclInation: Total Field Strength: Magnetic Dip: DeclInation DIte: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: 26.257° 57464.164 nT 80.755° September 05, 2001 BGGM 2001 True North +26.257° Well Head -' Grid Coordinates Geographic Coordinates MD I Incl I Azlm I 1VD I VSec I NI-5 I EI.W I DLS Northing I Eutlng Latitude I longitude (It) (°) (°) (It) (It) (It) (It) (o/100ft) (ftUS) (flUS) 0.00 0.00 177.70 0.00 0.00 0.00 0.00 0.00 5978097.98 583188.27 N 7021 0.477 W 149 1928.589 300.00 0.00 177.70 300.00 0.00 0.00 0.00 0.00 5978097.98 583188.27 N 70210.477 W 1491928.589 400.00 1.00 177.70 399.99 0.87 -0.87 0.04 1.00 5978097.11 583188.32 N 7021 0.468 W 149 1928.588 500.00 2.00 177.70 499.96 3.49 -3.49 0.14 1.00 5978094.49 583188.45 N 70210.443 W 1491928.585 600.00 3.00 177.70 599.86 7.85 -7.85 0.32 1.00 5978090.14 583188.68 N 7021 0.400 W 149 1928.580 700.00 4.00 177.70 699.68 13.96 -13.95 0.56 1.00 5978084.04 583188.99 N 70210.340 W 1491928.573 800.00 5.00 177.70 799.37 21.80 -21.79 0.87 1.00 5978076.20 583189.38 N 70 210.263 W 149 1928.564 900.00 6.50 177.70 898.86 31.82 -31.80 1.28 1.50 5978066,20 583189.90 N 7021 0.164 W 149 1928.552 1000.00 8.00 177.70 998.06 44.44 -44.41 1.78 1.50 5978053.60 583190.54 N 70 21 0.040 W 149 19 28.537 '-' ) 1100.00 9.50 177.70 1096.89 59.65 -59.60 2.39 1.50 5978038.42 583191.32 N 702059.891 W 149 1928.520 1200.00 11.00 177.70 1195.29 77.45 -77.38 3.11 1.50 5978020.65 583192.24 N 702059.716 W 1491928.499 1300.00 12.50 177.70 1293.19 97.81 -97.73 3.93 1.50 5978000.31 583193.28 N 702059.516 W 1491928.475 1400.00 14.00 177.70 1390.53 120.73 -120.63 4.85 1.50 5977977.42 583194.46 N 702059.291 W 149 1928.448 1500.00 15.50 177.70 1487.23 146.19 -146.07 5.87 1.50 5977952.00 583195.76 N 702059.040 W 1491928.418 1556.33 16.34 177.70 1541.40 161.64 -161.51 6.49 1.50 5977936.57 583196.55 N 702058.888 W 1491928.400 1600.00 17.00 177.70 1583.23 174.17 -174.03 6.99 1.50 5977924.06 583197.19 N 702058.765 W 1491928.385 1700.00 18.50 177.70 1678.47 204.66 -204.49 8.21 1.50 5977893.61 583198.75 N 70 20 58.466 W 149 19 28.350 1708.37 18.63 177.70 1686.40 207.32 -207.15 8.32 1.50 5977890.96 583198.89 N 702058.440 W 1491928.346 Page 1 of 2 7/19/2001-11:57 AM Grid Coordinates Geographic Coordinates StItIon ID MD I Incl I Azim I TVD I VSec I NI-8 I EJ.W I DLS Northing I Easting Latitude I Longitude (It) (°) (°) (It) (ft) (It) (It) (0/100ft) (ftUS) (ftUS) End Bid 1733.33 19.00 177.70 1710.03 215.37 -215.20 8.64 1.50 5977882.91 583199.30 N 70 20 58.360 W 149 19 28.337 Base Permafrost 1882.85 19.00 177.70 1851.40 264.05 -263.83 10.60 0.00 5977834.31 583201.80 N 702057.882 W 149 1928.280 Bid 4/100 1983.33 19.00 177.70 1946.41 296.76 -296.52 11.91 0.00 5977801.64 583203.47 N 702057.561 W 149 1928.241 2000.00 19.67 177.70 1962.14 302.28 -302.04 12.13 4.00 5977796.12 583203.75 N 70 20 57.506 W 149 1928.235 SV3 2068.86 22.42 177.70 2026.40 327.00 -326.74 13.12 4.00 5977771.44 583205.02 N 70 20 57.263 W 1491928.206 2100.00 23.67 177.70 2055.06 339.19 -338.92 13.61 4.00 5977759.26 583205.64 N 702057.144 W 149 1928.192 2200.00 27.67 177.70 2145.17 382.50 -382.19 15.35 4.00 5977716,02 583207.86 N 702056.718 W 149 1928.141 SV2 2258.48 30.01 177.70 2196.40 410.70 -410.37 16.48 4.00 5977687,86 . 583209.30 N 702056.441 W 149 1928.108 2300.00 31.67 177.70 2232.05 431.98 -431.64 17.33 4.00 5977666.60 583210.39 N 702056.232 W 1491928.083 End Bid 2306.46 31.93 177.70 2237.54 435,39 -435.04 17.47 4.00 5977663,20 583210.57 N 702056.198 W 149 1928.079 ~ SV1 2635.02 31.93 177.70 2516.40 609.14 -608.65 24.42 0.00 5977489.70 583219.44 N 702054.491 W 149 1927.876 9-5/8" Csg Pt 2705.72 31.93 177.70 2576.40 646.52 -646.00 25.92 0.00 5977452,37 583221.36 N 702054.124 W 149 1927.832 UG4A 3035.62 31.93 177.70 2856.40 820.97 -820.31 32.91 0.00 5977278.16 583230.28 N 702052.409 W 1491927.628 UG3 3436.21 31.93 177.70 3196.40 1032.81 -1031.98 41.39 0.00 5977066.62 583241.11 N 702050.328 W 149 1927.380 UG1 3975.84 31.93 177.70 3654.40 1318.17 -1317.11 52,82 0.00 5976781.66 583255.70 N 702047.523 W 1491927.046 Ma 4285.71 31.93 177,70 3917.40 1482.04 -1480.85 59.38 0.00 5976618.02 583264.08 N 702045.913 W 149 1926.854 WS2 4579.08 31.93 177.70 4166.40 1637.18 -1635.86 65.59 0.00 5976463.10 583272.01 N 702044.388 W 1491926.673 WS1 4779.38 31.93 177.70 4336.40 1743.10 -1741.70 69,84 0.00 5976357.33 583277.43 N 702043.348 W 149 1926.549 Obf Base 5241.24 31.93 177.70 4728.40 1987.33 -1985.74 79.62 0.00 5976113.43 583289.92 N 702040.947 W 1491926.263 CM2 5680.72 31.93 177.70 5101.40 2219.73 -2217.95 88,92 0.00 5975881.36 583301.80 N 702038.664 W 149 1925.992 CM1 6558.49 31.93 177.70 5846.40 2683.91 -2681.76 107.51 0.00 5975417.83 583325.53 N 70 20 34.102 W 1491925.449 Top HRZ 7100.47 31.93 177.70 6306.40 2970.52 -2968.13 118.99 0.00 5975131.63 583340.19 N 702031.286 W 149 1925.113 Base HRZ 7312.55 31.93 177.70 6486.40 3082.67 -3080.19 123.48 0.00 5975019.64 583345.92 N 70 20 30.184 W 149 1924.982 K-1 7395.02 31.93 177.70 6556.40 3126.28 -3123.77 125.23 0.00 5974976.09 583348.16 N 70 20 29.755 W 149 1924.931 Top Kuparuk 7463.35 31.93 177.70 6614.39 3162.41 -3159.87 126.67 0.00 5974940.01 583350.00 N 70 20 29.400 W 1491924.889 Target 7463.36 31.93 177.70 6614.40 3162.42 -3159.88 126.67 0.00 5974940.00 583350.00 N 702029.400 W 149 1924.889 ) -. Kuparuk C 7485.75 31.93 177.70 6633.40 3174.25 -3171.71 127.15 0.00 5974928.18 583350.61 N 70 20 29.284 W 1491924.875 TMLV 8007.69 31.93 177.70 7076.39 3450.26 -3447.49 138.20 0.00 5974652.56 583364.72 N 702026.571 W 149 1924.552 TD I 7" Lnr Pt 8157.70 31.93 177.70 7203.71 3529.59 -3526.76 141.38 0.00 5974573.34 583368.78 N 702025.792 W 149 1924.460 Leaal Description: Northina (Y) fftUS1 Eastina IX) fftUS1 Surface: 2376 FSL 3728 FEL S34 T12N R11E UM 5978097.98 583188.27 Target: 4496 F5L 3608 FEL 53 T11N R11E UM 5974940.00 583350.00 BHL: 4129 F5L 3594 FEL S3 T11N R11E UM 5974573.34 583368.77 L-109 (P3) report. xis Page 2 of2 7/19/2001-11:57 AM III'. - - - Q) - ~~ 8~ 0 Q) -- > II .8 c: ro ;g -~ .:= . -CO a." Q) - em -~ ~~ .- Q) t::=rx: Q) > > Q)~ 2w I- 0-. 1000 _. 2000 ~. --- ~- -..- -_. ') ) VJ:R'1'J:CAL SBC'1'J:OI1 VJ:ZW Client: Alaska Drilling & Wells Well: L-109 (P3) Field: Prudhoe Bay Unit - WOA Structure: L-PAD Section At: 177.70 deg Date: July 19, 2001 Schlußlberger t KOP 1/100 300 MD 300 TVD 0.00' 177.70. az Odeparture J-..-.--..--.--'- ~.~~.~~~~~ :~2 ~~pa~e J;ncUlld l13~.MD .JJ1QJVD.. _.- 19.00' 177.70" az 215 departure --,. .".". ..-- -- .-.. SV5 1556 MO 1541 TVO _.. -- dO.- -.-. -- --, --- --- .- -.,. --". ..- - "--'. ,,-_. "'.- _.- --- -." -". -- .. ~.,.' -- ..-- -..." ".-- ~-- -- SV4 1708 MO 1686 TVO BIcI4ItGØ 1983 MD 1946 TVD - 1.9..00......17I...70..az 297 dllpartw:e .------ ..- -- .- --- --- --- Bãše P;"mãi(os¡-i883 MÓ-1851 TVO , End Bid 2308 MD 2238 TVD ',,~:>,/,,'~:-:::: ':,::~1:03.''',:~.71;¡o.''az.:::43S::dapartur.~ --:-"",,-.': ''':''''.'' -~_: _:.. , . - "" ".. , "-" ---- -'--' "".-- --- --"" --'- .- -" - .-- - SV3 2069 MO 2026 TVO .- -~:7 ~3:.c~~:::7 =~.D_.. Þ ~~- - --- - - - - - - - - --- ,- ,-- -.- -- .- - SV2 2258 MO 2196 TVO - - - - - -- - - .- -- .on -".. --.. ,,-- -- 3000 - 4000 _u 5000 -- 6000 - 7000 - --.. -..- ._-, -. ---, ...... ,-_. SV1 2635 MO 2516 TVO UG4A 3036 MO 2856 TVO - -.- --. -- ,-- -- .-- .-- -. - ......- - --- UG3 3436 MO 3196 TVD -. ~--- .---- -,- --- --- UG'- 3976 M"D 36s4 NO-' --., ,-- -" -- -" .- ~Mã'428¡¡Mb-39''-7 Tÿb .--- .- .- - -- --- ---- -- --- ~ -- -- --- --- -WS2 4579 MD 4166 NO'- - -------- WS 1 4779 M"D 43-36 TVD --- - --" 4_- -. - -- .-- --- -..- .- - --- Hold Angle 3' .930 -. otirSase 5241 M'O 4728 NO "~"., -- ..-- .- --, ,-- _.-. --- .,_. -,~ ..- --- CM2 5681 rV"IO 5101 NO -. - - -- - '- -- ..- cMi 6558 MD 5'6461'10'- -- - ,-- -- .- - - -- '-Top"HRZ 7fDO MO 6306 TVD . rervet 7463 MD 6614 TVD -- - 31.93' '77.70.8Z 3162 dep8ture =1="'== =;~:;: ~~; I \ TO/T1LnrPt 8158 MD 7204 TVD -- -- '_:Ì>~':~~~~az I 3000 4000 --, ,- -- - ~- --- -- -- -- '-Sa-sa HRz 7313 ~1b 6486"TVO--' -- .- - -- - -- -- ... - - ~tTi\<uiärui"14;M~~66~~ Nt; K~a;u~; ~8~~ ~~3~vè ;: = = = = ~ I i- i -lMC' ."',,, ",,-M - -1- -- - -- .. -- . ¡ - -- - ---- I I 0 1000 I I 2000 Vertical Section Departure at 177.70 deg from (0.0, O.O). (1 in = 1000 feet) ,.j.... ..Ii, ...! ___I, 0- -500 - -1000 - ^ ^ ^ I ~ 0 Z -1500- -2000 - I ~ :::> 0 en V V V -2500- -3000 - ) PLAR VIBW Client: Alaska Drilling & Well: L-109 (P3) . Field: Prudhoe Bay Unit Structure: L-PAD Scale: 1 in = 500 ft Date: 19-Jul-2001 Wells - WOA -1000 -500 0 500 ~I<OP''''''''"'' .."" ----,- 0.OO'I77.70'cO'N--OE-" ---Bid 1.11/100800 MO 799TVO 6.00' 177.7:)' IZ 22 S 1 E t---- End Bid 17S3 Me 1710 TVO 19.00. 177.:00' az 215 S 9 E --,.-.------ Bid 41100 1983 MO 1946 TVO 19.00. 177.:"0' az 297 S 12 E -------- End Bid 23011 MO 2238 TVO 31.9S. 177.:00. az 435 S 17 E 'l'xue Korth Mag Dee ( E 26.26° ) ~. .d 0 b.. ---------..-.-- $.l1li" CIII Pt27011 Me 2578 TVO S1.9S' 177-70' az 848 S 26 E :I: .0 õ: ~ 3" c:: g ~ ...,¡ ...,¡ :....a 0 0 ~) I \ -- -_/-\-// ~~= 7::;7~~ az e;~~~ 127 : ev \\ 0 ~ -3500 - \ \ I I c I I I -1000 -500 0 «< WEST TD/rlnrPt8158MD 7204fVO S1.9S' 177.70' az 3527 S 1.1 E I ~ 1000 500 EAST »> ) 1000 Schlußlbøruør -0 --500 --1000 ---1500 -. - -2000 --2500 --3000 ---3500 Polygon 1 2 3 4 -.--.--------'-------_"____n___. & % Site: PB L Pad ) Drilling Target Conf.: 99~," . Centre Location: Map Northing: 5974940.00 ft Map Easting : 583350.00 ft Latitude: 70020'29.400N +N/-S ft 404.44 398.79 -404.44 -395.58 --.-..------ Target: L-I09 +E/-W ft -395.58 114.43 395.58 -404.44 C0 & rv c§J "V< -< -, tell: L-I09 Jased on: Planned Program Vertical Depth: 6538.00 ft below Mean Sea Level Local +N/-S: -3159.87 ft Local +E/-W: 126.75 ft Longitude: 149° 19'24.889W Northing ft 5975340.00 5975340.00 5974540.00 5974540.00 \}~ 00 Easting ft 582950.00 583460.00 583750.00 582950.00 -_.._.""._-_.._----"----~- '- ~c9C \iOOO ~200 / ) Schlumberger Anticollision Report ') , I I I " I,." , " ,I ,I, 'I . 'C()m..~ny: ' ~I'~~~A~..".'.,.....'. Field:,', . .'... .. "Ie~~~ ~y Reference Site: . .PB'lP$d, 'Refèren~eWell:' . " L~109 ' .' Rêfe~n~e ,Welipath:'~lal1' ~~109 ,.~' ," I -........:..-...:...-....:-..:......-_~-_:..:-..; ~- NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 100.00 ft Depth Range: 28.50 to 8157.70 ft Maximum Radius: 1000.00 ft ... : I ,I' ': : I : .' ' . : , I : ~ II. I II ' : : : II !.: ' ' ¡'II,I "1,1;11. """,,1 ',,' ;' ',I. '."', '1:,,"1'1,:/111:'1'1"1' ',' 'I I I ,1,1 I I I I I' .:Ð.ie:'!.7~Oj20ô1,<'! '. ':;rI"'e:'1'9;49:2~:'. ...,I,:':i:,;:I,i;:lli..I."li.I,',I:'::':'.:, '...., "', '.. ,'.;,,~I:'.'., ,., I "Ço-,-~buI.e(N')~e~~~,:;. ,.1, ,Well;~~1'09.Tru~~~rth Vettle"(fV'Ð)~efe..ente;:' . I L-10976:4 ' . . 'I," I I '.'; "",,', "I' ";. I_-~'::_~.I'! Reference: Error Model: Scan Method: Error Surface: , Db; S~~~se ----- Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing --'~-----'-"~---"-'--_.- ---,------- ---.-- ------....---------.....--------'-- ._-,,--_..._-..._--'--'-~'----'._._"_...~-- Survey Program for Definitive Wellpath Date: 12/26/2000 Validated: No Planned From To Survey ft ft 76.40 500.00 500.00 8157.70 Version: Toolcode 4 Tool Name ----~,._._-_._-_._._.__._- .-.--.---.--- Planned: Plan #3 V1 Planned: Plan #3 V1 CB-GYRO-SS MWD Camera based gyro single shots MWD - Standard -"---.--.----'.--'.------_____"M- --,---_._---~"__..M."____-_."-'._.'-'--'.".- . Casing Points 2705.74 2576.40 8157.70 7203.45 9.625 7.000 12.250 8.500 95/8" 7" "- -".-'--.-'.---'.'''..'------''..-.---..--"...-...- .,-.-----.--..--.---.----".---- ---------.-. Summary :":":~:'.r'.:-"""-,--7-"'~'-!7"-""-'-;9ìf~~":~~.I~"¡~';::~....,..,....,. . !" Site. "I" ./ ,.."..'", ,.,".' "'.'1. 1.,"'.",:: I.W.~I..r ..".. .":.":. .., I,.'. .,...~'t., " l,-~_t.._-"--_':~Lj'~!L.~L¡¡,":,:."'::".'! :';.I:I::::j1i:'I,".'~:)::::'IIII::,., EX NWE#1 NWE1-01 EX NWE#1 NWE1-01 EX NWE#1 NWE1-02 PB L Pad L-01 PB L Pad L-107 PB L Pad L-110 PB L Pad L-114 PB L Pad L-115 PB L Pad L-116 I: ":':'.1.', ,I,.,"" :",,:0,' .":il:' 'I:',::, :,.11: 1"':,.:1'" ,1':'1."11",.,.' ,', ': ",: :':1'", 1.:-''11' "I'I:I~ 'II" III" '.1:0.:", 11'''''i',: ."'1,'; )": nM'~I' ,::,. '1,1 ',':~., "".:',1" ' " ',;' 'I~' ,,,:,~~,. ':" I'." :,'1 :i"I' ,..,,:, , , :"'''.' 'd,,' I', , I " " ','1' I,','.. ,.,:..':.jl"IIII$: :1:.I:I,!:II':I:.I':',I":"I"I:';!I:~e{"q~~~..:'I"M~~~~'I:;,:;,ç~~trl:I':I~~T;,II¡¡;:":'.,I,,: ...\,~,~~~~.e', ".:."'....."""":I!:"./I ..,.".: "":'., '':',"".,., . . '.I"..W~~ln.~"I"'.."II.'I'.'I:,.I.: .11".'1"':1;. "i.. I , ',11,1:':11.":11' .'."'~Y:.I'Mþ.I!I'1 I.,'" ':'.'I!I'I;:':'IMQ.'li,~lr;:I,:'lpi..Ii4:~I".'~~'{III"".:I.IÐ~¥I~tlo,," I . ~:"., ~., -.,ITD"." I in, .~:.:' ."!:,"i/,' " ".. .1, . : ":';" ": :.'::':'~:,II;.,I:: ,,; '.~;.I~" I':,.' ::." :~ I ,', '" 1'.:::::: ,',I,;, 1:,1:: I :,\11 ..ill,; ': ;::1::11,':-: 'I: ': '; I.I,:I:! ,,' ,.::.1 I~":"",~:.:."":": ':1 i;:,:.ï,; I: :.::.',1' ~''I.,' ,1::,',1'.:. ;.I~ ,I~'I):,:,. :'&::, ':' :: :'1 : '::: I,':::,' "'I ~', :' II.: ":' 1..: '.:':':1,,"": I' ,I \~/' ~",I".;'ft~I' . :~ I' ,.,~. ::~ I' "1':1' ¡ ,,':':¡ I' ~ I, "1':"1", "ft' ' " : ,I,: '1":': ,; :'"':.: II,,~:,I, I 7: -J I 1 NWE1-01 V3 300.00 300.06 282.10 6.41 275.69 Pass: Major Risk NWE1-01A VO 300.00 300.06 282,10 6.41 275.69 Pass: Major Risk NWE1-02 V2 494.86 500.00 235.10 9.91 225.19 Pass: Major Risk L-01 V12 499.52 500.00 72.21 9.94 62.27 Pass: Major Risk Plan L-107 V10 Plan: L 698.77 700.00 88.15 13.73 74.42 Pass: Major Risk Plan L-110 V5 Plan: PI 500.33 500,00 46.29 10,93 35.36 Pass: Major Risk Plan L-114 V8 Plan: PI 800.62 800.00 118.27 15.46 102.80 Pass: Major Risk Plan L-115 V6 Plan: PI 600.03 600.00 75.04 17,67 57.36 Pass: Major Risk L-116 V7 499.97 500.00 15.20 8.79 6.45 Pass: Major Risk -"."-'''.'--'''-.---.<.",--.,.....''- - - --_.._..._-_._.-"._'."-'~._._.'-'- ~_.,---._._..~.,._-_._..._._----_. R__'__.--"-. ---------.-----. '_..-'--__M_~_'-"'-'-- . ) ') L-109 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates were observed in both NWE offset wells. These are expected to be encountered near the base of the Permafrost at 1850' and near the TD hole section as well. . Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: . The production section will be drilled with a recommended mud weight of 10.3 ppg to ensure shale stability in the HRZ shale. Read the Shale Drilling Recommended Practice. . Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. . FAULTS: The well trajectory is not expected to intersect any faults. If losses are unexpected losses are encountered, consult the Lost Circulation Decision Tree for recommended LCM treatments. . KICK TOLERANCE: With 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.4 ppg at the surface casing shoe, 10.3 ppg mud in the hole, kick tolerance is 25 bbls. . L-Pad development may have "kick tolerances" in the 25 bbl range or less. At least 100' prior to entering the Kuparuk reservoir, the drill crews will hold a safety meeting to discuss steps to ensure that a heightened awareness of kick detection will be in place while drilling/tripping through the intermediate/production intervals. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells NEW 1-01 and NEW 1-02 did not report H2S as being present. As a precaution Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page 1 of 1 Re: L-109 quarter section issue- Permit to Drill . ) Subject: Re: L-109 quarter section issue- Permit to Drill Date: Tue, 21 May 2002 15:24:49 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: nMagee, D Neiln <MageeDN@BP.com> ) t'Magee, D Neiln wrote: ~C2Jr:J X\ù~~ \\ ß'Q '" CJ-- '> "'Ç-<!: èJA ~ <YO ~~\ \ > Tom, ~ c . ~"" 'Ï : This well is back on the schedule, due to spud in about 12 days time after ~0 ~ ~ ,\; \ > the current well V-102. You'll remember this one was delayed due to quarter ~ ~\( , > section issues immediately prior to spud late last year. ("(Lc{t~ ,. / > f¡.he Permit t.o Drill was submitted 10-9-01. The well is identical to the one ~ (A . > permitted however it has been shortened by roughly 300' TVD to avoid a > potential fault. V C -0 ~ > The well coordinates are as follows: Q )\. > Surface: 2376 FSL, 3728'FEL, See 34, T12N, R11 E > Top Kuparuk: 4496 FSL, 3707'FEL, See 03, T11N, R11E > BHL: 4320'FSL, 3719'FEL, See 03, T11 N, R11 E > > Will the submitted 401 need to be freshened to show the new spud date > anticipated as 1 June, or are we good to go as submitted? Please let me know > if anything else is needed and 1'1/ provide it to you. > > Regards, Neil Magee > Neil, Shortening the TD should not affect what you have submitted. No additional paperwork is needed. Tom > -----Original Message----- > From: Jane Willíamson [mailto.'Jane Williamson((D.admin.state.ak.us] > Sent: Wednesday, May 15, 2002 3:49 PM > To: Smith, Bruce W > Cc: Camille 0 Taylor; Daniel T Seamount JR; Winton G Aubert; Thomas E > Maunder; Stephen F Davies; Robert P Crandall > Subject: Re: L-109 quarter section issue > > Bruce, > I have spoken with the Commissioners and other staff members as to your > request > to submit the 401 application for permit to drill without separate > application > for spacing exception. A separate spacing exeption will not be required. > However, production from the well cannot occur until the pool rules have > been > completed. > > The reasons that it is acceptable to proceed with drilling in this > particular > case without application for spacing exception are: > * a hearing was held concerning Borealis pool rules, > * 40 Acre spacing was specifically requested by BP within their 10f2 5/21/02 3:25 PM Re: L-109 quarter section issue- Permit to Drill ) ) > application, > * no objection was made by the public > * we have no technical problems with 40 acre spacing requested > * We anticipate we will have rules out before your planned drilling start, > but > definitely by May 30, within 30 day period of the end of hearing. > > Give me a call if you have questions. > > Jane Williamson > A OGCC Reservoir Engineer > > "Smith, Bruce W" wrote: > > > Tom and Jane, > > Good morning, > > Would like to get some guidance from both of you, we have now spud V-102. > > This well is expected to be completed in 10 days. Our next well is L-109. > > This well has a quarter section rule violation. Our drilling program is > > moving much quicker than expected, planned 14-17 days a well, actual 11-14 > > days. We scheduled, expecting the findings of the Rules by this date. > Can > > you give me an idea on when the findings will be complete? Second can we > > forward the drilling permit for L-109, get it signed since we are deemed > > complete for the Pool Rules? Anything you can do to get back to me today > > would be greatly appreciated, if the permit is not possible we will be > > pulling several people off other projects to start fire fighting. > > Thank you for your help. » > > Bruce W. Smith > > BP Exploration (Alaska) > > Western New Developments Engineer > > PO Box 196612 MS 6-5 > > Anchorage AK 99519-6612 > > 907-564-5093 Tom Maunder <tom maunder~admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 20f2 ~/~ 1/0? 3:25 PIV L-I09i Logging ) ) Subject: L-I09i Logging Date: Tue, 23 Apr 2002 13 :41 :41 -0800 From: Winton Aubert <Winton_Aubert@admin.state.ak.us> Organization: AOGCC To: cranelr@bp.com CC: Camille 0 Taylor <cammy_taylor@admin.state.ak.us>, Daniel Seamount <dan_seamount@admin.state.ak.us>, Robert P Crandall <bob_crandall@admin.state.ak.us> Lowell, This confirms AOGCC's logging requirements for L-109i, in consideration of the diverter waiver granted for L-119i. The Commission requires a calibrated gas log (non-arbitrary units) and GR, SP, Resistivity, Neutron Density, and Sonic logs in the L-109i surface well bore. Please contact me if additional clarification is needed. Thank you, Winton Aubert AOGCC 793-1231 1 of 1 5/21/20024:07 PM L-119 surface Hole ) ') Subject: L-119 suñace Hole Date: Tue, 23 Apr 2002 15:20:59 -0500 From: "Odenthal, Robert 5" <OdenthRS@BP.com> To: '"Tom_Maunder@admin.state.ak.us'" <Tom_Maunder@admin.state.ak.us> CC: "Magee, 0 Neil" <MageeDN@BP .com> «L-119 Surface hole.ZIP» Robert 5. Odenthal BP Exploration Alaska Drilling Engineer Work #: 907-564-4387 Celt #: 907-440-0185 E-mail: odenthrs@bp.com Name: L-119 Surface hole.ZIP ~L-119 Surface hole,ZIP Type: Zip Compressed Data (application/x-zip-compressed) Encoding: base64 1 of 1 5/21/023:23 PM ) April 23, 2002 Tom Maunder Alaska Oil and Gas Commission Re: L-119 Surface Hole Drilling Operations Dear Sir: I. Daily Breakdown of Operations 3/27/2002----Spud the well at 7:30 a.m.. Directionally drilled :trom 107-1456'. Drilling with the following parameters: MW 9.3-9.6 WOB 25k GPM 650 RPM 70 3/28/2002----Continued drilling from 1476-1756' (base of the perma:trost). Same drilling parameters used. Circulated the well clean. POH to the top of the HWDP (500'). Wellbore was in good condition. Intermitted drag 15k. No swabbing and no losses. RIH and wash to bottom the last 90'. No fill in the hole. Continued drilling with same parameters :trom 1756-2944' TD. POR for 9 5/8" casing. Intermitted overpull of 25k. No losses or swabbing. II. Mud Conditioning As per our standard practice when reaching the base of the permafrost and starting drilling towards TD, we added 2 ppb Lecithin and maintained this to TD. We also maintained mud viscosity between 200-250 and never had to adjust the flowrate down :trom the 650 gpm as hydrate breakout did not pose a problem. III. Rig Personnel Viewpoints In talking with the rig personnel and geologic staff, they said they did not see the signs or operational affects related to hydrate breakout or presence. ) ) IV. Epoch Gas Meter Epoch gas meter was to be used ITom spud to TD of this well. There were some communication problems with the equipment and we only captured from roughly 2200' MD (SV3) to TD total gas exceeded a 100 units. That data is below: DEPTH, TOTAL_GAS, RATE_PENF, FEET, UNITS, FT/HR, 2225.6 106.0 85.8 2225.9 111.6 85.8 2226.3 115.4 81.7 2226.6 122,0 81.7 2227.0 128.5 89.8 2227.4 132.3 89.8 2227.8 115.4 89.8 2228.3 127.6 97.5 2228.8 121.0 97.5 2229.2 122.0 113.7 2229.7 111.6 113.7 2230.2 107.9 117.7 2230.6 103.2 117.7 2243. 1 105.1 135.0 2244.7 107.9 120.6 2245.3 106.0 130.2 2245.8 101.3 130.2 2247.0 114.4 152.6 2247.7 107.9 152.6 2248.3 112.6 149.0 2248.9 110.7 149.0 2249.4 100.4 147.6 2250.1 112.6 139.6 2250.7 114.4 139.6 2251,3 118.2 152.1 2251.9 106.0 152.1 2252.5 119.1 145.9 2253.0 119.1 131.0 2253,5 120.1 128.7 2254.1 123.8 128.7 2254.6 122.9 128.7 2255.1 115.4 127.8 2255.7 127.6 127.8 2256.3 133.2 133.9 2256.9 129.5 133.9 2257.5 126.6 145.7 2258.0 162.3 132.0 2258.6 151.0 130.8 2259.2 152.0 139.3 2260.0 164.2 158.1 2260.6 2261.4 2262.1 2262.8 2263.4 2264.2 2264.9 2265.7 2266.4 2266.9 2267.2 2267.7 2268.1 2268.8 2269.5 2270.3 2271.1 2271.7 2272.3 2272,9 2273.7 2274.3 2275.0 2275.6 2292.5 2293.6 2294.9 2297.6 2298.2 2299.1 2300.0 2300.8 2301.7 2302.3 2303.1 2303.7 2304.4 2305.2 2305.9 2307.0 2307.9 2308.7 2309.6 2310.4 2311,3 2312.5 2313.2 2313.9 171.7 170.8 190.5 206.4 193.3 217.7 210.2 231.8 220.5 218.6 209.2 202.7 217.7 182.0 198.9 180.1 173.6 170,8 135,1 152.9 135.1 124.8 111,6 103.2 100.4 106.0 111.6 142.6 131,3 124.8 142.6 127.6 132.3 137.9 137.0 132.3 143.5 134.2 145.4 147.3 148.2 152.0 147.3 137.0 151.0 162.3 155.7 178.3 ') ') 176.9 169.4 179.1 179.1 153.3 171.2 171,2 184.8 187.9 147.0 125.5 125.5 99.1 99.1 151.0 183.9 178.6 178.6 150.7 150.7 156.1 163.2 162.0 162.0 196.9 198.7 325.1 222.0 224.3 215.1 212.1 212.5 212.5 151.7 229.5 205.8 132.7 177.9 177.9 225.2 255.8 236.1 189.1 213.4 204.5 261.4 211.4 194.7 2314.3 2317,0 2317.0 2317.0 2317.0 2317.0 2317.0 2317.0 2317.0 2317.0 2317.0, 2317.0 2317.0 2317.0 2317.0 2317.0 2317.0 2317.0 2317.0 2317.0 2317.0 2317.0 2317.0 2317.0 2317.0 2317.0 2706.5 2706.9 2707.3 2707.8 180.1 105.1 106.0 112.6 130.4 131.3 139.8 140.7 149.2 150.1 154.8 165.1 166.1 168.9 171.7 175.4 176.4 176.4 178.3 179.2 183.9 183.9 184.8 184.8 185.8 203.6 100.4 102.2 114.4 107.9, ') 167.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 110.7 0.0 0.0 49.7 0.0 0.0 57.6 74.2 0.0 49.7 45.8 38.9 0,0 68.3 68.3 86.4 86.4 If you need any additional information or further clarification, please do not hesitate to contact me. Sincerely Yours, Robert S. Odenthal Further L Pad Operations ) ) Subject: Further L Pad Operations Date: Tue, 02 Apr 2002 12:59:30 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Robert Odenthal <OdenthRS@BP.com>, Lowell Crane <cranelr@bp.com> CC: Jody J Colombie <jody_colombie@admin.state.ak.us>, Cammy Oechsli <Cammy - Oechsli@admin.state.ak.us>, Daniel T Seamount JR <dan_seamount@admin.state.ak.us>, Bob Crandall <bob_crandall@admin.state.ak.us>, Steve Davies <steve_davies@admin.state.ak.us>, Winton G Aubert <winton - aubert@admin.state.ak.us> Robert and Lowell, The rig is presently drilling on L-119i and I understand that it will then move to V pad to do three wells (V-IOI--PTD 202-056, V-I06--to be permitted and V-I02--202-033). This schedule change has been done to relieve some of the concerns with the simultaneous operations on L pad. When the rig returns to L pad, present plans are to drill L-I09i and then maybe L-I05i. I talked with Robert last week and indicated we would like to have updated information regarding the most recently drilled surface hole. You have previously provided a mud weight plot and some comments on any gas or absence thereof. On receipt of that information, we will then issue the next permit. Please call with any questions. Tom Maunder, PE AOGCC ,.. ... ..." "..,. ..".. . -, ." W """..N '^ .\.-, ""'1"""','11'''''''._',,,...'1.'' .. ^ w v v"....",,'y. "Y',"."" ^ M'''''''''..W; "\.,\. . ...".........-.....o<..,..............~ ........ Tom Maunder <tom maunder(Q¿admin.state.ak.us> ! Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission .. .........~.............."""..........................."....... ''''''''''''''J'' ..........",""",..,...v-v.........~J ."'"'~'''''''''''''''''''''''''v..MM,........,~.......w.n'''''''''-''''' 1 of 1 .^ ,. ^"..J 4/5/02 1 :03 PM . r . C) () Prudhoe Bay Unit L-Pad Diverter Waiver Notes to File March 22, 2002 The intent of a diverter system on a drill rig is to allow an uncontrolled well flow to be directed away from the rig floor, thereby enhancing the safety of a drilling crew by pennitting them additional escape time. Regulation 20 AAC 25.035 (c) provides specific requirements for a diverter system. Regulation 20. AAC 25.035 (h) pennits the Commission to waive diverter requirements in certain circumstances. Variances may be granted if the operator provides an equally effective means of diverting flow away from the drill rig, or if drilling experience in the near vicinity indicates that a diverter system is not necessary. BP is currently seeking a variance from diverter requirements for further drilling on the Prudhoe Bay Unit L-Pad. Their argument is that a diverter should not be required based on past drilling experience on L- Pad. To date, 13 wells have been drilled from the pad without incident, which argues in favor of a diverter waiver. However, a confidential map provided by Robert Hunter ofBP (dated Oct. 15,2001) shows that L-Pad is situated near the middle of a world-class gas hydrate accumulation, and within an area interpreted by BP to contain free gas associated with the hydrate deposits. Hunter's infonnation augments USGS and drilling experience that the immediate area is known to contain. hydrates. The Commission's principle concern at L-Pad is free-gas possibly associated with the gas hydrate deposits. In fact, wire line logs from well L-I06 indicate approximately 25' of free gas reservoir at the base of a thick gas hydrate zone. Free gas may constitute a drilling hazard when improper operating practices allow such gas to flow into the well bore. At present, the area and vertical distribution of this free-gas beneath the hydrate zone and its occurrence within the hydrate zone is poorly understood by the Commission and by industry. Gas hydrates are the topic of current research by the USGS and at least two industry teams: one headed by BP, and another involving Anadarko. BP has designed and constructed L-Pad as a small-footprint operation with closely spaced wells and tightly packed equipment. Many of the facilities and flow lines are currently in place. In its present configuration, use of a standard diverter line is not possible. In many places on the pad, a diverter of required length and configuration (75', as straight as possible) simply will not fit between the rig and the piping/facilities already in place. Where it will fit, the diverter will point toward the centerline of the pad, and it will be aimed directly at existing or planned piping and/or facilities. There are no other rigs available today on the North Slope that will pennit the diverter line to be aimed in any other, less hazardous direction. If the Commission were to require a diverter line, it must be lifted over, threaded through, and built around existing, active, above-ground piping, greatly increasing the potential of construction-related accident arid spill. Modification of the diverter line to include curves or targeted- T intersections could impair its effectiveness and would likely not ease its construction. ~- C) () In such a drilling situation where shallow-hazard uncertainty exists, the Commission would normally require a diverter. However, because of the design and existing infrastructure on L- Pad, the Commission is now forced to choose the lesser of two evils. While the hydrates and potentially associated free-gas are still sources of uncertainty, drilling standards and practices have been developed and implemented that have allowed BP to drill 13 wells from L- Pad without incident. Although the existence of hydrates in the intended drilling path is known and successful mitigation strategies have been employed in the drilling plans, there is still some potential for a drilling accident caused by free gas associated with the hydrates. The probability of that occurrence is very low. In contrast, a construction-related accident or spill caused by placement and assembly of the diverter line near existing infrastructure is considered by the Commission to be a greater risk. Therefore, a diverter waiver should be granted. To offset the lack of a diverter system, and to increase the safety of the drilling crew, the Commission should require a high-resolution system capable of quickly detecting any influx of gas or fluid into the mud system on all future wells drilled from Prudhoe Bay Unit L-Pad. In addition, a full suite of well logs should be required from surface to total depth on the well that reaches furthest from L-106 (which currently has a complete suite of well logs ). The purpose of this additional logging is to provide the Commission with more data that will increase our confidence that no significant zones of free gas or other shallow drilling hazards exist above 2580 feet TVD in the L- Pad area. '-L- ~a.-<-- < . . 3"2Z,0L- ) H194724 DATE 07/31/01 CHECK NO. 00194724 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 )72701 CK0727010 PYMT COMMENTS: HANDL:NG INST: 100.00 100.00 Pernit To Drill Fee S/H - Terrie Hubble X4628 L-\cA : ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL .~ 100.00 ,100. OJL BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 19 4 7 2 4 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00194724 JAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 07/31/01 AMOLJNT $100.00 fo The JRDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 \(, , -'-~_., '~,', ",' ... ".~ I- , n /11'!~ ! I ~ ~,_~I..~,/.~ 118 . g l, ? 2 l, 118 I: 0 l, . 2 0 ~ a g 5 I: 0 0 8 l, l, . g 118 CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORA TION INJECTION WELL r/' INJECTION WELL REDRILL ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME fß!1 L.- IDC? ¿. CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNUL¿~~OSAL NO ANNULAR DISPOSAL <-) YES ANNULAR DISPOSAL THIS WELL ) "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, . API No. . Production should continue to be reported as a function of the original API number stated above. . In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated.. . ANNULUS <--J YES + SP ACING EXCEPTION / Templates are located m drive\jody\templates \~tt. Enclosed is the approved application for permit to drill the above referenced wen. The permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to perforate and .¥' udu(!e is contingent upon issuance of a conservation order approving a spacing exception. ~ ? (Company Name) will assume the liability of any protest to the spacing exception that may occur. , ~u - WELL PERMIT CHECKLIST ~'I-ì OMPAN, Y, ð*. WELL NAME L"-/bC¡¿ PROGRAM: exp -, ' dev - redrll- serv --L wellbore seg _ann. disposal para req FIELD&POOL~Vr)/ßD I2cfgjú~.d~!I~ITCLASs5ß~rV 2- 01AJ~ GEOLAREA RttO UNIT# O)/lðGJ ON/OFFSHORE /1...- _~}¡i1Aff, -5Þ l #'J ADMINISTRATION 1. Permit fee attached. .~. . ~ . . . . . . . . . . . . . . . . . N ~ / . ,+z . -,4 g' 0:. -L..n 0cL -f-,', , (- i 2. Le~se numberappropnate:T'. . . . . . . . . . . . . . . . . . M of<.. ~u.r . lð~ ~'::;V~""7VI-I 62 Z3f) 'fu~r (..;7(- ~ ¡Y1+~I/4. ~ 3. Unique well name and number... . . . . . . . . . . . . . . . , ~Dèv'~ It.þL P i:7)~/'fI/1P " i lJ II j/ I / ~- j j p ," 4. Well located in a defined pool:** . . . . . . . . . . . . . . ~ ~~,J,.(olt. (6 ~ CI.?hfJ"1!111J11Ó!.C! 'J}jeG-p-y ft>1'''' ÞÒ~ ""f1W-, I''':t'':'-¡,.;(-=- OA1..,d ~l~rplr..l..f( 5. Well located proper distance from drilling unit boundary. . . . NvilAlI'1 ,ft.¿. ¡5;..-'rê-,A..t6 a..-~ ~ :.L-6- IJI'-<.5f ¿'è- t I/Ct,ki.Ak.c! :¡c~ Á?-/i ¡;ô<!/;', t?O tfG-¡¡ 6. Welll?cated proper di~tan~ fro~ ~ther ~ells.. . . . . . . . . 'ß!:::Jt4~fè5 ..¡4..F.~¿("L/..k.. te.v& 61/,;:-:.01 "J(.. ~:i! a-~, '~ .:5é/'-Y'ÞLdcr S/~..f{.:' , 7, SuffiCient acreage avallable'ln dnlhng Unit. ~. . . . . . . . Y ~/~, ~I t4 v'/ld~.f,\;~) aJ'\d ¿..t"'l''-I\e-d '1Iðl¿¿~JclG '~!~C.I:¡.I7Ì:--n5;. ê6t¡g--A Rc.dLZ 8. If deviated, is wellbóre plat included.. . . . . . . . . . , . . . ~N ¿¿¡/~::; / ~l ~~ t?.~~Qfrl ~ 24/ Jc:~~ 5~;,~"", ~'-/lfFI¿ ~l(16¿ #a.e ~(~~. " 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N K~"'I.LÁ /<.;--l.(( ~ /fW '1:):3 Ii 'W. //(:.. .Il-r-c.;,,'j-1 t4V.:.-<:..~c-x. ,t..u1(! i,e- ~l;',~. 10. Oper~tor has ~ppropria~e bond in force.. . . . . . . . . . . .. . N ,L..-'ldiC: e::t.è!e.G l1ôl vl~/«'Þ~ ':>'¡d.k~",d,~~0. ~~¡':et-'?1.'f!!..nf> .r¿f .J'0rðc!c!.,t~(~ 11. Permit can be Issued wIthout conservation order. . . . . . . . y("Ñ'i¿ve.l. , /I /It!1f-) GlO /V]// 6¿,..,~,?/~ f¡7" ÝÎ~ :>¡>~ '15 <q,'!f>þ? ~tf ~t;r4j'¿LJ.e.(, API:R DATE ( 12. Permit ca~'be issued without administrativ~ approval.. . . . . !?)N fJj\ .f}.:t:i;) 16 "~~'¿d ~'~Á. flvL- /(T';:.u..k ~ ~~4~(U:~'¡:' ,ÞlJ 1(,11 170 13. Can permit be approved before 15-day walt.. . . . . . . . . . '1'<!J ~~¿(")- -fo ~H ~ e.c...-h~ CU!..-.f,JrI"!:t tA'tf£ ~'t'J'1 L- Ptd /::,~.-1.Å1:- uÝ ENGINEERING 14. Conductor string provided . . . . . . . . .. . . . . . . . . . N 5:..J",¡v'ld~ 5l't"-ÇJ ~/{ . ßù- . 15. Surface casing protects all known USDWs. . . . . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . N 17. CMT vol adequate to .tie-in long string to surf csg. . . . . . . . N 18. CMT will cover alt known productive horizons. . . . .'. . . . . N +- '30 ~ð ~Ct's c; 19. Casing designs adequate for C, T. 8 & permafrost. . . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . N ¡..l'té$ ~ 21. If a re-dritl, has a 10-403 for abandonment been approved. . . Y N ¡'¡/A ~ \ , 22. Adequate wellbore separation proposed.. . . . . . . . . . .. ,f!) N CNm ~ ~ ::t\'- \"- ~ \G.~ 23. If diverter required, doe, s it meet regula~ions . . . . . . . . .. *~ N ~W&(...h' 6v Ct{JpU e <f Co r' . 24. Drilling .fluid program schematic & equip list adequate, . . . . N ' 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N , 26. BOPE press rating appropriate; test to 4000 psig. , N (Vi A S ¡? ':' Z 7 S (J f (A , 27. Choke r:nanifold C?mplies w/A~1 RP-:53 ,(May 84). . . . . . ", 82 N 28. Work will occur without operation shutdown. . . . . . . . . . . fjJ N . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ , 30. Permit can be issued w/o hydrogen sulfide measures. . . . .. ~ N . . . ,~ " 31. Da~a ~resented. on potential overpressure zones. . . . . . . [j) ~ ¡:1J-~rt.Jz. ,~.s ervo ¡ ," ,~?~ to'- rft~¡dc!- -Iv t, .IÇ,C? fj!f(j Ð'J1:.u.. ,I 32. SeIsmic anal~~ls of shallo~ gas zones. . . . . . . . . . . .. d~ ¡'¡/;1drt~,k$~~ -t-~ ~~ ø.ç /.J~Y'J/J14.,{m-:i -fa :.s" ,\2J-/-l/O ~ J... AP~ DATE 33. Seabed condition survey (if off-shore). . . . . . . '..:",~: fJf\ Y N U (j, ,)J,) 1{)~/7D I 34. Contact namelphone for weekly progress reports [e~ratory only) Y N , ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. " 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: RÞð - rtJ6A- WM '8~ CÐT s .~. t~~.6q,,"'\. JM~ I!n¡'7jo Z. APP~ DA TF \Nt¡t- ?/ ¡.'fO L It-~ ~/~~ . GEOLOGY APPR DATE Y N Y N "j~ ÚM.VLiÁI.M" [{Sf~ S-v( ~~~ ~~ 1- /.,.....:, -n..' þI ~ / ' ., Commentsllnstructions: 'I? / . ¿ff(;j - \.:Ð ( y/vl ~" PW-~ill<& ,fl' óLkf(¡.:O ( ~d<- /6 iA?<d, F"Y ac,:òu ''''''-17/,J,~'.~ : ::/~~5' . ~ /(i..p'VVt.A-ft.. ~eruo/r 11.Jl/('"~ IS CiJr>1:5/d.z~ F~.,.1 'f(~ ~L ?r~'(./L R,,)~~ ad (iv~ t"J..-~~14 tJ~i/~IUl-d 't¡ 6'0 9;)7- ~'- A '1è.t0 .-f-~e/f' r"n/ cod~ AA II 6L I/JJ() r-4 rrl ~ t.I£- S,2ILArlide-V ßluff ~ -IÏ~ ~. .~.., ' c:\msoffice\wordian\diana\checklist (rev. 11/01/100) c 0 Z 0 -I :E ::a -I m Z -I :I: en )- ::a m »