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Home My WebLink About205-138MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 14, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P-06B PRUDHOE BAY UNIT P-06B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/14/2024 P-06B 50-029-22166-02-00 205-138-0 W SPT 8683 2051380 2171 815 822 813 799 215 286 288 290 REQVAR P Guy Cook 5/9/2024 Two year MITIA to maximum injection pressure per AA AIO 3B.005. Water injection header at 2000 psi. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT P-06B Inspection Date: Tubing OA Packer Depth 451 2400 2315 2300IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC240508183216 BBL Pumped:4 BBL Returned:2.5 Friday, June 14, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 9 9 AIO 3B.005 James B. Regg Digitally signed by James B. Regg Date: 2024.06.14 14:40:48 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 15, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P-06B PRUDHOE BAY UNIT P-06B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/15/2022 P-06B 50-029-22166-02-00 205-138-0 W SPT 8683 2051380 2171 1019 1022 1021 1021 410 601 596 587 REQVAR P Adam Earl 5/26/2022 MIT-IA tested as per AIO 3B.005 to Max. Ant. Inj. Psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT P-06B Inspection Date: Tubing OA Packer Depth 559 2460 2368 2356IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220529073518 BBL Pumped:3.2 BBL Returned:3.1 Wednesday, June 15, 2022 Page 1 of 1 9 9 9 9 999 9 9 9 9MIT-IA tested as per AIO 3B.005 James B. Regg Digitally signed by James B. Regg Date: 2022.06.15 15:04:30 -08'00' 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): 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 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 P-06B DAD Acid, Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-138 50-029-22166-02-00 11800 Conductor Surface Intermediate Production Liner 9033 79 2646 9928 235 2153 11450 20" 10-3/4" 7-5/8" 5-1/2" 3-1/2" x 3-3/16" x 2-7/8" 9031 41 - 120 41 - 2687 38 - 9967 9739 - 9974 9647 - 11800 41 - 120 41 - 2687 38 - 8893 8728 - 8898 8662 - 9033 11450 2480 4790 6280 10530 11450 5210 6890 7740 10160 10087 - 11530 4-1/2" 12.6# 13Cr80 36 - 9744 8973 - 9025 Structural 4-1/2" TIW HBBP Packer 9677 9677 8683 Stan Golis Sr. Area Operations Manager Noel Nocas Noel.Nocas@hilcorp.com 907.564.5278 PRUDHOE BAY, PRUDHOE 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 13.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 0028288 No SSSV Installed 36 - 8731 8683 Perforations from 10087' - 11050' MD Pumped 48-bbls DAD Acid in two 24-bbl stages. Final treating pressure = 1450-psi. 0 3143 700 750 150 1127 321-231 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: By Samantha Carlisle at 10:18 am, Nov 23, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.11.22 17:27:19 -09'00' Stan Golis (880) MGR29DEC2021 RBDMS HEW 11/24/2021 SFD 11/29/2021 DSR-11/23/21 ACTIVITY DATE SUMMARY 11/10/2021 LRS 72 Assist CTU. (ACID). Pummped 24 bbls of DAD acid. FP surface equipment with 1.5 bbls of neat methanol. CTU spotted acid and left it soak for 30 minutes. Pumped another 24 bbls of DAD acid. Pumped 1.5 bbls of neat methanol to FP equipment. CTU spotted acid. Pumped 10 bbls of FW acid tube flush. Freeze protected surface lines with 3 bbls of 60/40 MeOH. CTU had control of the well upon departure. 11/10/2021 CTU #6 w1.75" CT .145 WT Job Objective: Acid,SBG, Mill CIBP to restore injectivity MIRU CTU, MU SLB Nozzle BHA. Valve crew troubleshoot SSV. RIH w/2" JSN. Tagged CIBP 10,249' MD, flag pipe. Circulate surface to surface w/diesel and KCI. Begin 2 stage 10% DAD acid treatment as per pump schedule. Lay in 5 bbls of DAD acid in liner, shut choke, and let soak for 30 minutes. Reciprocate across perf intervals 10,060' - 10,200' pumping acid stimulation as per program. Pick up above liner top and perform injectivity test. Pull to surface to pump SBG treatment and found reel swivel leaking. Pull into lubricator and close swab to change swivel. ***Job continued on 11/11/21*** 11/11/2021 CTU #6 w 1.75" CT .145" WT Job Objective: Acid, SBG, Mill CIBP to restore injectivity Change SLB leaking reel swivel and pressure test. Jet SBG from surface to CIBP, FP coil while Pooh. On surface make up Tbird milling BHA while waiting on SBG soak time. RIH w/Tbird milling BHA w/2.70" venturi burn shoe. Tag CIBP @ 10,249' MD verified at flagged pipe. Attempted to mill plug for 6 hours with no success. POOH to inspect tools ***Job continued on 11/12/21*** 11/12/2021 CTU #6 w 1.75" CT .145" WT Job Objective: Acid, SBG, Mill CIBP to restore injectivity POOH with 2.70" Venturi burnshoe BHA. Found minimal wear on shoe and parts of body lock ring in junk basket. Make up Tbird 2.70" junk milling BHA and RIH. Milled CIBP @ 10,249' MD and pushed to 3-3/16" x 2-7/8" crossover at 10,909' MD. Pumped 5 bbl powervis sweeps. Swapped coil over to diesel while POOH w/BHA. While POOH found hydraulic leak on the injector. Stack down injector for repairs (6.5hrs NPT). ***Job Continued on 11/13/21*** 11/13/2021 CTU #6 w 1.75" CT .145" WT Job Objective: Acid, SBG, Mill CIBP to restore injectivity Make up T-bird 2.30" milling BHA. RIH ang tag CIBP at 10,896'. Work CIBP down in 2-7/8" liner to top of 2-7/8" CIBP @ 11,431' ctm / 11,450' MD. POOH w/BHA. Make up jetting BHA & RIH. Reciprocate pipe across bottom perf interval @ 20 fpm while jetting SBG treatment. Injection pressure WHP 1076 psi @ 1.6 bpm. POOH w/BHA. RDMO CTU6. ***Pad Op POI on departure*** Daily Report of Well Operations PBU P-06B Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:205-138 6.API Number:50-029-22166-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028288 Property Designation (Lease Number):10. 341 H 8. PBU P-06B 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown DAD - Mud Acid Op Shutdown GAS GSTOR5WAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11800 Effective Depth MD: 13Cr80 11. 5/19/2021 Commission Representative: 15. Suspended Contact Name: Noel Nocas Contact Email: Noel.Nocas@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9033 Effective Depth TVD:Plugs (MD):Junk (MD): 5Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9677, 8683 No SSSV Installed Date: Liner 2153 3-1/2" x 3-3/16" x 2-7/8"9647 - 11800 8662 - 9033 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 41 - 2687 41 - 2687 14. Estimated Date for Commencing Operations: BOP Sketch 41 - 120 Structural 6890 Proposal Summary 13. Well Class after proposed work: 4-1/2" TIW HBBP Packer 10087 - 11530 8973 - 9025 4-1/2" 12.6#36 - 9744 Liner 10249 9038 10249, 11450 None 41 - 120 10-3/4" 7-5/8" Contact Phone:907.564.5278 Date: 4790 78 20"Conductor 2480 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2646 5210 Intermediate 9928 38 - 9967 38 - 8893 235 5-1/2"9739 - 9974 8728 - 8898 7740 6280 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 10:20 am, May 06, 2021 321-231 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.05.06 10:12:36 -08'00' Stan Golis (880) DSR-5/6/21SFD 5/6/2021MGR17MAY21 dts 5/17/2021 JLC 5/17/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.18 15:04:23 -08'00' RBDMS HEW 5/19/2021 10-404 Mud Acid Job Well: P-06B PTD: 205-138 Well Name:P-06B API Number:50-029-22166-02 Current Status:Operable, SI Rig:CTU Estimated Start Date:5/20/2020 Estimated Duration:5 Days Reg.Approval Req’std?N/A Date Reg. Approval Rec’vd:N/A Regulatory Contact:Abbie Barker Permit to Drill Number:2051380 First Call Engineer:Noel Nocas (907) 777-8449 (O)(907) 947-9533 (M) Second Call Engineer:Wyatt Rivard (907) 777-8547 (O)(509) 670-8001 (M) Maximum Expected BHP:3310 psi @ 8,800’ TVD 7.3 PPGE | (Average Ivishak BHP) Max. Anticipated Surface Pressure:2430psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:290 psi Min ID:2.37” TOL @ 10909’ MD Max Angle:103 Deg @ 10573’ MD Well Objective: The objective of this program is to perform a coiled tubing perforation wash and matrix DAD-mud acid stimulation to clear the well of any hydrocarbon deposits and near wellbore area of any formation damage to improve well injectivity. In addition a SBG treatment will be pumped on current open perfs and the CIBP will be milled out to increase injectivity and add support for nearby producers. -00 SBG - Schmoo-Be-Gone Mud Acid Job Well: P-06B PTD: 205-138 1.MIRU CT unit and pumpers. 2.MU and RIH w/ ~2” JSN for drift and acid stimulation. Drift to CIBP @ 10,249’ MD.PUH to ~10,200’ and flag pipe to reference bottom of reciprocation interval. Circulate in safe lube laden fluid while RIH as necessary (this can be 1% KCl as it will be circulated out w/ 3% NH4Cl prior to pumping mud acid). x If tag is encountered short of CIBP, attempt to jet through obstruction. If unable to jet through obstruction and it seems to be hard in nature, contact town for discussion on PU motor and mill. x NOTE:Well has minimal to no injectivity, so if a larger amount of fill is encountered, will most likely not be able to fluff-n-stuff and will need to cleanout to surface. 3.After well has been drifted to CIBP, PU to ~10,000’ MD and begin circulating fluids into the well per pump schedule below. x Will need to circulate in diesel FP, 3% NH4Cl fluid packing stage and DAD acid due to well having minimal to no injectivity. x Once all diesel has exited the CT and 3% NH4Cl is at the nozzle, begin RIH to flag still circulating to ensure liner gets swapped over to 3% NH4Cl. Once at CT flag, WSL discretion to stay parked or PUH to TOL to circulate remainder of brine fluid packing stage. x Pump schedule volumes should be such that diesel FP is in surface lines and down CTBS to ~2500’ MD when DAD acid has been laid into the liner. The spacer of 3% NH4Cl between acid stages is so there will not be acid in the surface lines while the 30-minute acid soak is happening. Please adjust pump schedule as necessary to make this happen as the CT volume was assumed to be 33 bbls when designing the pump schedule.With a 30- minute soak time, no FP should be necessary of surface lines. x NOTE:Well has a liquid packed annulus so be aware of AFE and bleed IA as necessary to keep IA pressure below 1000 psi. 4.With CT at 10,200’ MD and DAD acid at nozzle, PUH and lay in 5 bbls DAD acid into liner. Once above TOL, shut-in well and allow DAD acid to soak for 30 minutes. x If decision was to PUH to circulate in remainder of brine fluid packing stage, time out RIH to 10,200’ MD with DAD acid to nozzle and lay in acid. x Purpose of acid soak is clear any hydrocarbon deposits from the TOL and liner walls. 5.After soak time is complete, leave CTBS SI, bring pump back online going down the CT to inject acid and fluid into the formation. Begin RIH and continue with remainder of pump schedule. x Reciprocate from 10,200’ to 10,065’ MD while pumping acid stages so all perforations experience jetting action with acid. x When 3% NH4Cl spacer is at nozzle between acid stages, PUH and reciprocate from 9500’ down to CT flag to ensure any remaining DAD acid has been swept from TBG and liner. x Formation frac gradient of the Ivishak is ~0.65 psi/ft. In pressure, this equates to ~1915 psi WHP w/ a full column of 3% NH4Cl to the perforations. Max pressure while stimulating is 1850 psi to ensure stay below frac pressure. x If, after DAD acid soak, well still has no injectivity at 1850 psi, OK to increase max pressure to 2500 psi to establish injection. If still unable to establish injection, contact intervention engineer for discussion. 6.After all acid is out of the CT, make one last reciprocation from 9500’ down to 10,220’ MD to ensure all acid has been displaced from the TBG and liner. POOH to just above TOL and complete overflush. x While parked above TOL completing overflush, perform 10 minute injectivity tests at 0.5, 1, 1.5 and 2 bpm if possible. Mud Acid Job Well: P-06B PTD: 205-138 CT DAD-Mud Acid Pump Schedule Stage Description Step Fluid Type Volume( bbls) Cum. Volume (bbls) Pump Rate (bpm) WHP Pressure (psi)Comment Freeze Protect 1 Diesel 35 35 Max 1850 See details above Brine Fluid Packing 2 3% NH4Cl 87 122 Max 1850 See details above HCl Stage 3 90:10 DAD 24 146 1-2 1850 See details above Brine Spacer 4 3% NH4Cl 15 161 1-2 1850 See details above Mud Acid 4 9/1 Mud Acid 24 185 1-2 1850 See details above Overflush 5 3% NH4Cl 115 445 1-2 1850 See details above 7.POOH to surface once overflush is complete and prepare to pump SBG treatment. At WSL discretion to change nozzle. 8.Begin RIH pumping SBG treatment. x RIH at 80 fpm jetting at 1 bpm in the TBG (start from srfc). x RIH at 20 fpm jetting at 1 bpm in the liner. Complete a down-up pass from TOL to CIBP. x Can chase SBG down CT w/ 1% KCl x Estimated SBG volume should be ~180 bbls 9.After back to TOL and all SBG is out of CT, POOH. Allow the SBG to soak for appx 3-6 hours before milling on CIBP in step 10. Can start soak time when all SBG has exited the CT. After soak time bullhead SBG treatment away with PWI from injection line, or with 1% KCL (milling fluid) while milling on plug. 10.Pickup motor and Mill. The goal is to mill first CIBP at 10,249 and push down to CIBP at 11,450’MD. WSS discretion on burn over shoe to attempt to catch CIBP at XO or flat bottom mill. May need second run to mill core and push down into 2-7/8” liner. If injection is still poor, be careful when plug is milled to not allow plug body bits to stick coil. 11.Wash and reciprocate across bottom perforations and pump second SBG treatment with ~100bbls SBG. 12.If Pad Op will POI well upon RD, can RDMO CT unit. x If Pad Op will not POI well immediately upon CT RDMO, displace 75% of the TBG and liner volume w/ 1% KCl and FP (include previous FP volume in the 75%). Mud Acid Job Well: P-06B PTD: 205-138 Design Basis Volume to Top Perf:150.5 bbls (147 bbls TBG and 3.5 bbls liner) CTBS Volume to TOL (1.75” CT):118 bbls Gross Volume Across Perfs:0.7 bbls (92’ in 3-3/16” liner) Net Perf Footage:92’ of perfs covering Z4 Ivishak Acid Design:10.96 gpf 90:10 DAD Acid – 24 bbls 10.96 gpf 9/1 Mud Acid – 24 bbls Diversion Design:No diversion will be pumped Fluid Requirements Fluid Type Volume (gal)Volume (bbl) 3% NH4Cl + F103 9,114 217 DAD Acid 1,008 24 9/1 Mud Acid 1,008 24 Diesel 1,470 35 50/50 Methanol 210 5 Ammonium Chloride Recipe Additive SLB Code Concentration Quantity NH4Cl N/A 250 ppt 2279 lbs Surfactant F103 2 gpt 18.2 gal 90:10 DAD Acid Recipe Function SLB Code Concentration Quantity Acid Corrosion Inhibitor A264 6 gpt 6 gal Inhibitor Aid A201 40 gpt 40.3 gal Intensifier A153 5 ppt 5 lbs Emulsifier F103 15 gpt 15.1 gal Iron Control L058 20 ppt 20.1 lbs Anti-emulsifier W054 5 gpt 5 gal Xylene N/A 100 gpt 100.8 gal 9/1 Mud Acid Recipe Function SLB Code Concentration Quantity Acid Corrosion Inhibitor A264 6 gpt 6 gal Inhibitor Aid A201 40 gpt 40.3 gal Intensifier A153 5 ppt 5 lbs Flowback Aid F103 2 gpt 2 gal Iron Control L058 20 ppt 20.1 lbs Anti-emulsifier W054 5 gpt 5 gal Mutual Solvent U067 50 gpt 50.4 gal Mud Acid Job Well: P-06B PTD: 205-138 Current Schematic Mud Acid Job Well: P-06B PTD: 205-138 Proposed Schematic MEMORANDUM TO: Jim Regg �'jv f tc Ztjw P.I. Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 4, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. P -06B PRUDHOE BAY UNIT P -06B Ste: Inspector Reviewed By: P.I. Supry l7:f—1 Comm Well Name PRUDHOE BAY UNIT P -06B API Well Number 50-029-22166-02-00 Inspector Name: Bob Noble IBSp Num: mitRCN200516151701 Permit Number: 205-138-0 Inspection Date: 5/16/2020 - Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P -06B Type Inj w TVD PTD 2051380 Type Test sPT Test psi BBL Pumped: 3 9 - BBL Returned: 8683 Tubing 1708 - 1711 . -- 1708 - 1700 2718 54 - 2171 - 3,9 - IA 345 2790 2730 - OA 50 - 53 54 - Interval RBQVAR 1P/F P 1 Notes: 2 year MIT -IA to max IA injection pressure as per AIO 38.005 Thursday, June 4, 2020 Page I of 1 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed APR 3 U 201 Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casing ❑ Change Aro0�-gd C50' Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: DAD Muud A 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number: 205-158 3. Address'. P.O. Box 196612 Anchorage, AK99519-6612 Stratigraphic ❑ Service [a 1 6. API Number: 50-029-22166-02-00 7. Property Designation (Lease Number): ADL 028288 8. Well Name and Number: PBU P -06B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary'. Total Depth: measured 11800 feet Plugs measured 10249, 11450 feet true vertical 9033 feet Junk measured None feet Effective Depth: measured 10249 feet Packer measured 9877 feet true vertical 9038 feet Packer true vertical 8683 feet Casing. Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 41-120 41 -120 Surface 2646 10-3/4" 41-2687 41-2687 5210 2480 Intermediate 9928 7-5/8" 38-9967 38-8893 6890 4790 Liner 235 5-112" 9739-9974 8728-8898 7740 6280 Liner 2153 3-1/2" x 3-3/16" x 2-718" 9647-11800 8662-9033 Perforation Depth: Measured depth: 10087 - 11530 feet True vertical depth: 8973-9025 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 36-9744 36-8732 Packers and SSSV (type, measured and 4-1/2" TIW HBBP Packer 9677 8683 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Tag COP at 10,241' ctmd. PUH to 10,200' flag pipe. Circulate bums up with NH4CL. Lay in 5 bbls of 10% DAD antl across Paris. Park above TOL Close choke 8 let soak for 30 mins. At flag circulate NH4CL and first acid stage. Reciprocate across perfs and pump Acid Stim as per program- Overflush with 290 bbls of NH4CL. Intervals treated (measured): 10087'-10180' Treatment descriptions including volumes used and final pressure'. 10.96 gpf 90:10 DAD Acid - 24 bbls, 10.96 gpf 9/1 Mud Acid - 24 bbls Final Pressures: OA = 150 psi, IA = 650 psi, TBG = 1950 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Md Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In 200 1950 Subsequent to operation: 0 0 491 650 1950 14. Attachments: (re,imdp.r20MC25.07025071,&25,293) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 11WINJ ❑ WAG GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and corect to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 518-424 Authorized Name. Shnver, Tyson Contact Name: Shriver, Tyson Authorized Tile: Well Intervention Engineer Contact Email: Tyson.ShriverCbp.xxtm Authorized Signature: Date: L 3V/ Contact Phone: +1 9075644133 Form 10404 Revised 04/2017 1 17 './ ,� ROMS E( MAY 0 12019 submit Original Only 4/13/2019 CTU #8 - 1.75" Coil -- Job Objective: Acid Treatment MIRU.CTU. "Continued on 4/14/2019** CTU#8 1.75" Coiled Tubing. Job Objective: Acid Stimulation/Sbg Treatment MU & Rih w/ 2" DJN. Tag CIBP at 10,241' ctmd. PUH to 10,200' flag pipe. Circulate btms up with NH4CL. Lay in 5 bbls of 10% DAD acid across perfs. Park above TOL. Close choke & let soak for 30 mins. At flag circulate NH4CL and first acid stage. Reciprocate across perfs and pump Acid Stim as per program. Park above TOL and perform Injectivity Test] Breakdown: 0.5 bpm @1800 psi, 0.9 bpm @ 2500 psi, 1.8 bpm @ 3500 psi. Overflush with 290 bbls of NH4CL. Discuss Acid results with APE. Still continue with SBG treatment. Lay in SBG from flag to 2500' and inject SBG. 4/14/2019 **Continued on 04/15/19** CTU#8 1.75" Coiled Tubing. Job Objective: Acid Stimulation/Sbg Treatment Inject 10 bbls of SBG behind pipe. Displace SBG w/ 80 bbls of 1 % KCL & 38 bbls 60/40 freeze protect leaving -4 bbls of schmoo-b-gone in the Liner. RDMOL 4/15/2019 ***Job Complete*** TTS= 4-1/16' GW VV9-LHEAD= 5M FMC ACTUATOR= OTIS KB. ELEV = 92.11' REF ELEV = 9211' BF. ELEV = 53.72' KOP= 4900 M"a Angle= 103" @ 1057Y Datum MD= 9964' Datum TVD = 8800' SS 10-3/4' CSG, 45.5#, NT -8Q D = 9.950- 2687' Minimum ID = 2.37" @ 10909' TOP OF 2-718" LNR SAFETY NOTES: H2S READINGS AVERAGE 125 ppm P_0^ WHEN ON MI. WELL REQUIRES A SSSV WHEN ON v ML ORIGINAL WELL (P-06) IS NOT SHOWN ON DIAGRAM. "'4-12" CHROME TBG* -WELL ANGLE> 70" @ 10185'. O2103' 4-12" OTIS SSSV NP, ID= 3.813" GAS LFT MAN RR -S ST MD TVD DEV TYPE VLV LATCH PORI DATE 5 2985 2985 0 CAMCO *DIY BK 0 05/27/16 4 5514 5481 24 CAMOO *DMR' BK 0 05127/16 3 7729 7224 39 CAMDD 'DIY BK 0 05/27/16 2 9267 8389 43 CAMOD 'DMA' BK 0 05127/16 1 9636 8654 44 CAMOO -DMY BK 0 04/18104 * STA #2, #3, #4, & #5 = DMTS NAVE FRUEDENBERG PACKING "MANDREL COV6t®w/CEMENT (10120105 DIMS) gaAr 3 70' DFPLOY SLV. D = 3 00- PERFORATION SULMRY PRUDHOE BAY UNIT WELL. P -06B PHtMT No: 2051380 AH No: 50-029-22166-02 SEC 31, T11 N, R13E, 2506' FSL 8 1963' FVVL 9664' -14-12' PKR SWS NP, ID= 3.813" (BENNO PIPE) 05123/91 SJA ORIGINALCOMPLEnON Note. Refer to Production OB for historical 9666 3-1/2- HES X NP, D = 2.813' SPF INTERVAL 9677' 7-5/8"X4-1/2' TTN HBBP PKR (BEN ND PIPE) I/2" LNR, 8.81#, L-80 STL, .0087 bpf, D = 2.990' 9699 9699' 3-12' X 3-3/16' XO, ID = 2.786" 05/01118 2' 9709' 4-12' PKR SWS NP, D = 3 813' O 07/30/18 9731' 2 4-1' PKR SWM NP, MILL®TO 3.80" BEHIND TOP OF 5-12' LNR, ^9739' 8739' 7-58' X 5-112' TNV LNR HGR W/7B5 CT LNR 4-12" TBG, 12.6#, 13 -CR .0152 bpf, D = 3.958" 9742' 9743' 4-12' VVLF3a, D = 3.958' NOTE: TAILPIPE WAS BACKED OFF 8 IS RESTING ON 5-112" LNR TOP 7-518" CSG, 29.7#, NT -95 -HS, D=6.875' 9966' JV0HPSTOCK(10/I3/05)jj 9974' ELM MLLOUT V44DOW (P -06B) 9974' - 9982' PERFORATION SULMRY PRUDHOE BAY UNIT WELL. P -06B PHtMT No: 2051380 AH No: 50-029-22166-02 SEC 31, T11 N, R13E, 2506' FSL 8 1963' FVVL Rff LOG: MVVLYENTBSGRCJSROP ON 1025105 ANGLE AT TOP PERF 55` @ 10087' 05123/91 SJA ORIGINALCOMPLEnON Note. Refer to Production OB for historical perf data SIZE SPF INTERVAL OpnfSgz DATE 2" 6 10087 - 10149 O 05/01118 2' 6 10150-10180 O 07/30/18 2" 6 10925-11050 C 10127/05 2' 6 11490-11530 C 1027/05 LNR 6.2#, L-80 TCI, I 1 -0-9w bpf, D = 2 80" PBTD11�� 3.70" BKR RETREVALBE BPw /SUPT'ORT PPE TO TD 11696' 2-7/8' LNR 6.16#, L-80 STL, .0058 bpf, D = 2.441" 118OW 11450' 1-12-718" CIPB PRUDHOE BAY UNIT WELL. P -06B PHtMT No: 2051380 AH No: 50-029-22166-02 SEC 31, T11 N, R13E, 2506' FSL 8 1963' FVVL DATE REV BY CO&#A34TS DATE RLV BY COMM94TS 05123/91 SJA ORIGINALCOMPLEnON 05108/18 NXW/JMDSETC13P&ADPERFS 12/251197 PARKER CTDSIIIETRACK(P-06A) 07/31/18 BTNJMD AD-FRFS(07/30/18) 10129/05 NORDICI CTD SIDETRACK (P-060) 09/20118 JNJJMD OKB, PH, 8 BF/LNR DEPTH CORRECTION 04OZ12 RCT/ PJC SET PX PLUG (4/18/12) 06/05/12 RKT/JMD PULLED PSC PLUG (06101/12) BP Exploration (Alaska) 05131/16 JAR/JMD GLV CJO (05/27/16) THE STATE °fALASKA GOVERNOR BILL WALKER Tyson Shriver Well Intervention Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU P -06B Permit to Drill Number: 205-138 Sundry Number: 318-424 Dear Mr. Shriver: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W W W.aogcc.Cla5ka.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair 't\ DATED this day of October, 2018. RBDM94" OCT 1 A 118 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ FractureStimulate ❑ Repair Well ❑ Operations shu own Suspend ❑ Perforate ❑ Other Stimulate 0 - Pull Tubing ❑ Change Approved Program ❑ Plug for Retlrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other DAD -Mud Acid 0 ' 2. Operator Name: BP Exploration (Alaska), Inc 4, Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 205-138 ' 3. Address. P.O. Box 198612 Anchorage, AK , 99519-8612 Stratigraphic 11 Service 0' 6. API Numbec 50-029-22166-02-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? WII planned perforations require a spacing exception? Yes ❑ No 0 PBU P -06B 9. Property Designation (Lease Number): 10. Field/Pools. ADL 028288 ' PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effeosve Depth TVD: MPSP (psi): Plugs (MD). Junk (MD): 11800 - 9033 10249 9038 10249.11450 None Casing Length Size MD TVD Bunt Collapse Structural Conductor 78 20" 41-120 41-120 Surface 2646 10-3/4" 41-2687 41-2687 5210 2480 Intermediate 9928 7-5/8" 38 - 9967 38 - 8893 6890 4790 Production 235 5-1/2" 9739-9974 6728-8898 7740 6280 Liner 2153 3-1/2" x 3-3/16" x 2-7/8" 9647-11800 8662-9033 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10087- 11530 8973-9025 4-1/7 12.6# 13Cr80 36-9744 Packer and SSSV Type: 4112" TI W HBBP Packer Packers and SSSV MD (ft) and TVD (ft): 9677/8683 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0• 14. Estimated Date for Commencing Operations: October 15, 2018 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdci ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is We and the procedure approved herein will not Contact Name' Shnver, Tyson be deviated from without prior written approval. Contact Email Tyson.ShnverQbp.cem Authorized Name: Shriver, Tyson Contact Phone. +1 9075644133 Authorized Title: Well Intervention Engineer Authorized Signature: %], Date: K' /a•J/ �8' w COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I U Z4 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ❑ Post Initial Injection MIT Req'd? Yes No CI Spacing Exception Required? Yes ❑ No & Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: 10I t tQ, ORIGINAL RBDMS"CT 112018 nfI208-01-r re Submit Formmand Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate fir$- °9rt��l8 10-403 Sundry Application for Well PBU P -06B PTD# 205-138 Expected Start Date: October 15, 2018 Current condition of well: WAG Injection Well, Operable, Offline: Gas Injection Rate: N/A Injection Pressure: N/A Shut-in Wellhead Pressure: 179 psi Reservoirpressure: 3307 psi Well objective(s): The objective of this procedure is to perform a coiled tubing perforation wash and matrix DAD -Mud acid stimulation to clear the well of any hydrocarbon deposits and near wellbore area of any formation damage to improve well injectivity. Proposed program: 1. Drift to CIBP, perform DAD -Mud Acid stimulation per detailed Word procedure. Record injectivity improvements throughout job between each of the acid stages BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Design Basis Volume to Top Perf: 150.5 bbls 147 bbls TBG and 3.5 bbls liner CTBS Volume to TOL (1.75" CT): 118 bbls Gross Volume Across Perfs: 0.7 bbls 92' in 3-3/16" liner Net Perf Footage: 92' of perfs covering Z4 Ivishak Acid Design: 10.96 gpf 90:10 DAD Acid - 24 bbls 10.96 qpf 9/1 Mud Acid - 24 bbls Diversion Design: No diversion will be pumped Fluid Requirements Fluid Type Volume al Volume bbl 3% NH4CI + F103 15,120 -360 DAD Acid 1,008 24 9/1 Mud Acid 1,008 24 Diesel 1,470 35 50/50 Methanol 210 5 Ammonium Chloride Recipe Additive SLB Code Concentration Quantity NH4CI N/A 250 ppt 5397 Ibs Surfactant F103 2 gpt 49 gall 90:10 DAD Acid Recipe Function SLB Code Concentration Quantity Acid Corrosion Inhibitor A264 6 qPt 6 gal Inhibitor Aid A201 40 gpt 40.3 gal Intensifier A153 5 ppt 5 Ibs Flowback Aid F103 15 gpt 3 gal Iron Control L058 20Ppt PPt 15.1 Ibs Anti -emulsifier W054 5 qpt 5 gal Xylene N/A 100 gpt 100.8 qal 9/1 Mud Acid Recipe Function SLB Code Concentration Quantity Acid Corrosion Inhibitor A264 6 gpt 6 gal Inhibitor Aid A201 40 gpt 40.3 gal Intensifier A153 5 ppt 5 Ibs Flowback Aid F103 2 gpt 2 gal Iron Control I L058 20 PPt 15.1 Ibs Anti -emulsifier W054 5 gpt 5 gal Mutual Solvent U067 50 gpt 50.4 qal Coiled Tubing Drift and perform DAD-Mud Acid Stimulation 1. MIRU CT unit and SLB pumpers. 2. MU and RIH w/ -2" JSN for drift and acid stimulation. Drift to CIBP @ 10,249' MD. PUH to -10,200' and flag pipe to reference bottom of reciprocation interval. Circulate in safe lube laden fluid while RIH as necessary (this can be 1 % KCI as it will be circulated out w/ 3% NH4CI prior to pumping mud acid). • If tag is encountered short of CIBP, attempt to jet through obstruction. If unable to jet through obstruction and it seems to be hard in nature, contact town for discussion on PU motor and mill. • NOTE: Well has minimal to no injectivity, so if a larger amount of fill is encountered, will most likely not be able to fluff-n-stuff and will need to cleanout to surface. 3. After well has been drifted to CIBP, PU to -10,000' MD and begin circulating fluids into the well per pump schedule below. • Will need to circulate in diesel FP, 3% NH4CI fluid packing stage and DAD acid due to well having minimal to no injectivity. • Once all diesel has exited the CT and 3% NH4CI is at the nozzle, begin RIH to flag still circulating to ensure liner gets swapped over to 3% NH4CI. Once at CT flag, WSL discretion to stay parked or PUH to TOL to circulate remainder of brine fluid packing stage. • Pump schedule volumes should be such that diesel FP is in surface lines and down CTBS to -2500' MD when DAD acid has been laid into the liner. The spacer of 3% NH4CI between acid stages is so there will not be acid in the surface lines while the 30-minute acid soak is happening. Please adjust pump schedule as necessary to make this happen as the CT volume was assumed to be 33 bbls when designing the pump schedule. With a 30-minute soak time, no FP should be necessary of surface lines. • NOTE: Well has a liquid packed annulus so be aware of AFE and bleed IA as necessary to keep IA pressure below 1000 psi. 4. With CT at 10,200' MD and DAD acid at nozzle, PUH and lay in 5 bbls DAD acid into liner. Once above TOL, shut-in well and allow DAD acid to soak for 30 minutes. • If decision was to PUH to circulate in remainder of brine fluid packing stage, time out RIH to 10,200' MD with DAD acid to nozzle and lay in acid. • Purpose of acid soak is clear any hydrocarbon deposits from the TOL and liner walls. 5. After soak time is complete, leave CTBS SI, bring pump back online going down the CT to inject acid and fluid into the formation. Begin RIH and continue with remainder of pump schedule. • Reciprocate from 10,200' to 10,065' MD while pumping acid stages so all perforations experience jetting action with acid. • When 3% NH4CI spacer is at nozzle between acid stages, PUH and reciprocate from 9500' down to CT flag to ensure any remaining DAD acid has been swept from TBG and liner. • Formation frac gradient of the Ivishak is -0.65 psi/ft. In pressure, this equates to -1915 psi WHP w/ a full column of 3% NH4CI to the perforations. Max pressure while stimulating is 1850 psi to ensure stay below frac pressure. 6. After all acid is out of the CT, make one last reciprocation from 9500' down to 10,220' MD to ensure all acid has been displaced from the TBG and liner. PUH to just above TOL and complete overflush. • While parked above TOL completing overflush, perform 10 minute injectivity tests at 0.5, 1, 1.5 and 2 bpm if possible. 7. Empty all brine tanks on location during overflush stage. POOH, pump diesel freeze protect into TBG and FP CT as necessary. RDMO SLB FB pumping and CT units. CT DAD -Mud Acid Pump Schedule Stage Description Step Fluid Type Volume bbls) Cum. Volume (bbis) Pump Rate (b m(psi) Pump Pressure Comment Freeze Protect 1 Diesel 35 35 Max 1850 See details above Brine Fluid Packing 2 3% NH4CI 87 122 Max 1850 See details above HCI Stage 3 90:10 DAD 24 146 1-2 1850 See details above Brine Spacer 4 3% NH4CI 15 161 1-2 1850 See details above Mud Acid 4 9/1 Mud Acid 24 185 1-2 1850 See details above Overflush 5 3% NH4CI 255 425 1-2 1850 See details above TREE= 4-1/16"CNV WELLHEAD = 5M FMC ACTUATOR = OTIS KB. ELEV = 92.11' REP ELEV = 92.11' BF. ELEV = 53.72' KOP= 4900' Max Angle 103" @ 10573' Datum MD= 9964' Datum TVD= 6666 SS 10-3/4" CSG, 45.5#, NT -80, D = 9.950" Minimum ID =2.37' @ 10909' TOP OF 2-7/8" LNR TOP OF 5-1/2" LNR 4-1/2" TBG, 12.6#, 13 -CK .0152 bpf, D = 3.958" 1 7-5/8" CSG, 29.7#, NT -95 -HS, D = 6.875° I (10/13/05) -9739' 9742' PERFORATION SUMMARY MD REL LOG: M WD'EVNR/SGRC/SROP ON 10/25/05 ANGLE AT TOP PERF: 55" @ 10087' TYPE Note: Refer to Production DB for historical pert data SIZE SPF IJTHRVAL Opn1Sgz DATE 2" 6 10087 - 10149 O 05/01/18 2" 6 10150-10180 O 07/30/18 2" 6 10925 - 11050 C 10/27/05 2" 6 11490 - 11530 C 10/27/05 P -06B 101 3-3/16" LNR 6.2#, L-80 TCI, .0076 bpf, D = 2.80• SAFETY NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON MI. WELL REQUIRES A SSSV WHEN ON ML ORIGINAL WELL (P-06) IS NOT SHOWN ON DIAGRAM. —4-112" CHROME TBG—WELL ANGLE> 70° @ 10185'. OTLS SSSV NIP A] =I R13° GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH POR! DATE 5 2985 2985 0 CAM1CD 'DM1Y BK 0 05/27/16 4 5514 5481 24 CAMOO `DMY BK 0 05/27/16 3 7729 7224 39 CAMCO 'DMY BK 0 05/27/16 2 9267 8389 43 CAMCO `DMY BK 0 05/27/16 1 9636 8654 44 CAMCO "DM1Y BK 0 04/18/04 ' STA #2, #3, #4, & 95 = DMY'S HAVE FRUEDE NBE RG PACKING —MANDREL COVERED w/CEMENT (10120105 DIMS) 9647- 3.70" DEPLOY SLV, D=3.00" 3-1/2" HES X NP, U = 2.813" 1 7-5/8" X 4-1/2' TNV HBBP PKR (1 3-112" X 3-3/16' XO. D = 2.786• 970��4-1%2-H(K SWJ NY,D=3.813- 9731' 4-1/2" PKR SWN NP, MLLED TO 3.80• I BEHIND 973W 7-5/8" X 5-1/2" TNV LNR HGR W/TBS I CT LNR 9743' 4-1/2' WLEG, D=3.958• NOTE TAILPIPE WAS BACKED OFF & IS RESTING ON 5-112- LNR TOP M LOUT WINDOW (P-066) 9974' - 9982' tr 0249'—I 2-78- WFT EXT RANGE CIBP(I 1 10909' 1 13.70" BKR REFRLVA LBE BP w/SUPPORT PPE TO TD 1 2-7/8" LNR 6.16#, L-80 STL, .0058 bpf, D = 2.441" 13-3/16" X 2-7/8' XO, D = 2.441" I PRUDHOE BAY UNIT WELL: P -06B FER14T No: 2051380 AP N o 50-029-22166-02 SEC 31, T11N, R13E, 2506' FSL & 1963' FVUL DATE REV BY COMMENTS DATE REV BY COMNHNTS 05123191 SIA ORIGINALCOMPLETION 05/08/18 NXW/JMDSEFCIBP&ADPE3TS 12/26197 PARIQR CTD SIDETRACK(P-06A)07/31/18 BTNJMD ADPEFFS(07/30/18) 10/29105 NORDIC? CTD SIDETRACK (P -06B) 09/20/18 JNUJMD OKB, REF, & BF/LNR DBH TH CORRECTION 04/22/12 RCT/ PJC SET PX RUG (4/18(12) 06/05/12 RKT/JMD PULLED PX FLUG (06/01/12) BP Exploration (Alaska) 05/31/16 JARIJMD GLV CIO (05/27/16) STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COM ON REPORT OF SUNDRY WELL OPERAS ' 1. Operations Performed Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program D Plug for Reddll 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set CIBP II 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 205-138 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22166-02-00 7. Property Designation(Lease Number): ADL 028288 8. Well Name and Number: PBU P-06B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 11800 feet Plugs measured 10249,11450 feet true vertical 9033 feet Junk measured None feet Effective Depth: measured 10249 feet Packer measured 9677 feet true vertical 9038 feet Packer true vertical 8683 feet Casing: Length: Size: MD: TVD: Burst: Collapse: 1 Structural I Conductor 78 20" 41-120 41-120 0 0 Surface 2646 10-3/4" 41 -2687 41 -2687 5210 2480 Intermediate 9928 7-5/8" 38-9967 38-8893 6890 4790 Liner 235 5-1/2" 9739-9974 8728-8898 7740 6280 Liner 2153 3-1/2"x 3-3/16"x 2-7/8" 9647-11800 8662-9033 10160/8520/12350 10530/7660/13890 Perforation Depth: Measured depth: 10587-11530 feet SCANNED JUN 1 1 20 True vertical depth: 8973-9025 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 36-9744 36-8732 Packers and SSSV(type,measured and 4-1/2"TIW HBBP Packer 9677 8683 true vertical depth) RECEIVE D No SSSV Installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): MAY 2 3 2018 Treatment descriptions including volumes used and final pressure: AOGCC 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 2794 500 900 • Subsequent to operation: 0 0 1 100 1950 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development 0 Service RI Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 WAG p GINJ ❑ SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-079 Authorized Name: Haffener,Jordan Contact Name: Haffener,Jordan Authorized Title: Production Engineer Contact Email: Jordan.Haffenertbp.com Authorized Signature: Date: 5/Z,Ag�� Contact Phone: +1 9075645383 Form 10-404 Revised 04/2017 r ,./6/i g' RBDMS NAY 2 5 no Submit Original Only • • wks*, „0„ .4v Ar Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) May 16, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Plug Perforations (Set CIBP) and Perforate, covered under Approved Sundry #318-079 for Well PBU P-06B, PTD #205-138. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • • Daily Report of Well Operations PBU P-06B ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL***(perforating) TAG MCX @ 2,103' MD WI 3.805"G.RING. PULL MCX FROM 2,103' MD. 4/28/2018 ***JOB CONTINUED ON 4/29/18*** ***JOB CONTINUED FROM 4/28/18***(perforating) DRIFTED W/10'x 2.50" DUMMY POWER JET OMEGA PERF GUN (od =2.78")TO 3-3/16"XO @ 9,699' MD (unable to get deeper) BRUSH AND FLUSH WI 3-1/2" BRUSH, 2.74"GAUGE RING TO DEVIATION @ 10,250' SLM LRS PUMPED 163bbIs DIESEL FOR BRUSH AND FLUSH RE-DRIFTED WI 10'x 2.50" DUMMY POWER JET OMEGA PERF GUN (od =2.78") TO 3-3/16" XO @ 9,699' MD (unable to get deeper) DRIFTED W/10'x 2.50" DUMMY POWER JET PERF GUN (od =2.66")TO DOGLEGS @ 10,103' SLM (unable to get deeper) 4/29/2018 ***WELL S/I ON DEPARTURE*** T/I/0=420/70/50 Temp=S/I Assist Slickline (PERFORATING) Pumped 163 bbls amb. diesel down tbg to load and assist SL in flushing sand. SL in control of well at LRS departure. IA/OA-OTG. 4/29/2018 FWHP-Vac/31/38 ***WELL SHUT-IN ON ARRIVAL*** (SLB E-LINE PERFORATING) INITIAL T/I/O= 700/100/0 PSI RUN 1: RIH W/31'X 2.00" POWERJET HSD, 6 SPF, 60 DEG PHASE. PERFORATED INTERVAL= 10118' - 10149'. CCL TO TOP SHOT= 3.25', CCL STOP DEPTH = 10114.75'. RUN 2: RIH W/31'X 2.00" POWERJET HSD, 6 SPF, 60 DEG PHASE. PERFORATED INTERVAL= 10087- 10118'. CCL TO TOP SHOT= 3.25', CCL STOP DEPTH = 10083.75'. RIH 3: W/WFT 2 7/8" EXT- RANGE CIBP. ALL RUNS TIE INTO HALLIBURTON GAMMA RAY LOG DATED 25-OCT-2005. 5/1/2018 ***JOB CONTINUED ON 2-MAY-2018*** ***JOB CONTINUED FROM 1-MAY-2018*** SET WFT 2-7/8" EXT-RANGE CIBP ME @ 10250'. CCL TO MID ELEMENT=9.9'. CCL STOP DEPTH = 10240.1'. TOP OF CIBP @ 10249'. FINAL T/I/O =400/100/0 PSI 5/2/2018 ***JOB COMPLETE 2-MAY-2018, WELL LEFT S/I ON DEPARTURE*** Fluids Summary Bbls Type 166 Diesel 38 Crude 4 60/40 Methanol TREE= 4-1/16"CAN TES:H2S ACTUpm MELDATOR EAR 5M FMC • P_O 6 B ORIMI.WELL REQUIRES P-06)ISNOTSHOWN ON AVERAGE 125 N ACTUATOR= FMC • ON MI. REQUIRES A SSSV WHEN ON KB.LEV= 77_90' DIAGRAM-*"4-1/2"CHROMETBG**"WELL ANGLE> BF.ELEV= 55.41' 70"r%' 10185'. KOP= 4900' Max Angle= 103" _.-... Datum _ Q 10 2103' —14-1/2"OTtS SSSV NP,D=3.813" 9964' 0 Datum TVD= 8800'SS GAS LFT MANDRELS 10-3/4"CSG,45.5#,NT-80,D=9.950" —{ 2687' ST MD ND DEV TYPE VLV LATCH PORT DATE 5 2985 2985 0 CAMCO 'CMA'' BK 0 05/27/16 I 4 5514 5481 24 CAIVCO `DMY BK 0 05/27/16 Iyl 3 7729 7224 39 CAMCO 'DMY BK 0 05/27/16 2 9267 8389 43 CAMCO *DRAY BK 0 05/27/16 Minimum ID =2.37" ( 10909' 1 9636 8654 44 CAMCO "MY BK 0 04/18/04 TOP OF 2-7/8" LN R #3,#4,&#5=DMY'S HAVE FRIJEDErEERG PACKING **MANDREL COVERED w/CEMENT(10/20/05 DIMS) I' P. 964T —13.70"DEPLOY SLV,D=3.00" 1 1 1I/ k —14-1/2"R42 SWS NP,D=3.813"(BMW)PIPE) r 1 [ 9666' I—3-1/2"HES X NP,D=2.813" i�0 p+Z 9677' —17-5/8"X 4-1/2"TAN I-BBP PKR(BEHIND PIPE) j 3-1/2"LW,8.81#,L-80 STL,.0087 bpf,D=2.990" —I 9699' :, # 9699' —I3-112"X 3-3H6"XO,ID=2.786" .1 c 9709' —14-1/2"PKR SWS NP,D=3.813" 9731' —(4-1/2"PKR SWN NP,MLLE')TO 3.80" BEHIND TOP OF 5-1/2"LNR H "9139' 1� 1 - 9739' H7-5/8"X 5-1/2"TNV LNR HGR w/TBS CT LNR 4-1/2"TBG,12.6#,13-CR,.0152 bpf,D=3.958" 9742' 11 1 X14 114 9743' 4-1/2"WLEG,D=3.958" •11 1 . NOTE: TAILPIPE HAS BACK®OFF& &MI �1; ' IS RESTING ON 5-112"LIR TOP 7-5/8"CSG,29 7#,NT-95-HS,D=6.875" —1 9966' �1$ O1, 4 WHPSTOCK(10/13/05) — 9974' ELM 3',''.,.'.•., MLLOUT MLLOUT WINDOW(P-068) 9974'-9982' '11,,,11 ` 10249' —2-7/8"VVFT EXT RANGE CEP(05/02/18) 11111,, 11111114 1, / 4 ::::s1 / 111.11. 10909' —1 3-3/16"X 2-7/8"XO,ID=2.441" 1111 1�1�1�11 PERFORATION StivIMARY 3-3/16"LNR,62#,L-80 TCI, — 10909' ` 11450' —2-7/8"CPB REF LOG:WYEWR/SGRC/SROP ON 10/25/05 .0076 bpf,D=2.80" / (09/21/10) ANGLE AT TOP PERF:55"@ 10087' Note:Refer to Production DB for historical pert data SIZE SFF INTERVAL Opn/Sqz DATE RIM — 11561' iiiti 2' 6 10087-10149 0 05/01/18 N.//_ 2" 6 10925-11050 C 10/27/05 3.70"BKR RETREVALBE BP w/SUPPORT PPE TO TD —I I 11596' 2" 6 11490-11530 C 10/27/05 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,ID=2.441" — 1159T WI { 11800' - I"' — DATE REV BY CONTENTS DATE REV BY COMMENTS PRWHOE BAY UNT 05/23/91 SJA ORIGINAL COMPLETION 04/22/12 RCT/PJC SET PX PLUG(4/18/12) WELL: P-06B 12/25/97 PARKER CTD SIDETRACK(P-06A) 06/05/12 RKT/JMO PULLED PX PLUG(06/01/12) PERNT No:"2051380 10/29/05 NORDIC1 CTD SIDETRACK(P-06B) 05/31/16 JAR/JMD GLV C/O(05/27/16) AR No: 50-029-22166-02 09/22/10 SPB/PJC SET CBP(09/21/10) 05/08/18 NXW/JMD SET CBP&ADPERFS SEC 31,T11 N,R13E,2506'FSL&1963'FIM_ 02/10/11 MB/JMD ADDED SSSV SAFETY NOTE 01/18/12 TITTYJMD ADDEDH2S SAFETY NOTE BP Exploration(Alaska) MEMORANDA • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / DATE: Tuesday,May 22,2018 P.I.Supervisor �l ZI t SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. P-06B FROM: Adam Earl PRUDHOE BAY UNIT P-06B Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Ji NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT P-06B API Well Number 50-029-22166-02-00 Inspector Name: Adam Earl Permit Number: 205-138-0 Inspection Date: 5/15/2018 Insp Num: mitAGE180515145318 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P-06B Type Inj W `TVD 8683 ' Tubing 1894 " 1894 1897' 1894 ' PTD 2051380 Type Test SPT Test psi 2171 " IA 38 2500 ' 2447 ' 2436 BBL Pumped: 6 " BBL Returned: 4.4 - OA 49 53 - 54 54 - Intervali REQVAR P/F P ,/ Notes: Tested as per A10 3B.005 SEAMED JUN 0 1202 Tuesday,May 22,2018 Page 1 of 1 OF To, • • f g*•e\� Iy/, e THE STATE Alaska Oil and Gas w rihP Of LAsK Conservation Commission lr;E 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASFax: 907.276.7542 www.aogcc.alaska.gov Ryan Thompsonsta _ , "xF ; t Interventions Engineer � � BP Exploration(Alaska) Inc. P.O Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Oil Pool, PBU P-06B Permit to Drill Number: 205-13 8 Sundry Number: 318-079 Dear Mr. Thompson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 6(02:g1— – Hollis S. French Chair DATED this ( day of March,2018. - ._ H18 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI•N FEB 2 7 APPLICATION FOR SUNDRY APPROVALS 2018 ~ 20 AAC 25.280 0715 3 f 1//5? 1. Type of Request: Abandon ❑ Plug Perforations 0- Fracture Stimulate ❑ Repair Well ❑ ,Q3 n❑ Suspend ❑ Perforate 0. Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 205-138' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic ❑ Service H• 6. API Number: 50-029-22166-02-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU P-06B • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028288 • PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 11800 • 9033 • 11450 9031 11450 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 37-117 37-117 Surface 2648 10-3/4" 39-2687 39-2687 5210 2480 Intermediate 9930 7-5/8" 37-9967 37-8893 6890 4790 Liner 235 5-1/2" 9739-9974 8728-8898 7740 6280 Liner 2153 3-1/2"x3-3/16"x2-7/8" 9647-11800 8662-9033 10160/8520/13450 10530/7660/13890 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10925-11050 8999-9024 4-1/2"12.6# 13Cr80 34-9744 Packers and SSSV Type: 4-1/2"TIW HBBP PKR Packers and SSSV MD(ft)and TVD(ft): 9677/8683 4-1/2"OTIS NM-10 SSSV 2103/2103 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic ❑ Development 0 Service 0 ' 14.Estimated Date for Commencing Operations: 3/15/2018 15. Well Status after proposed work: Oil ❑ WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 • GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Thompson,Ryan be deviated from without prior written approval. Contact Email: RYAN.THOMPSON@bp.com Authorized Name: Thompson,Ryan Contact Phone: +1 907 564 4535 Authorized SiInterventions ar Authorized Signature: Date: 2 L�I / COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3) ' d -.O Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No tic. Spacing Exception Required? Yes 0 Nolsd Subsequent Form Required: /t 2 401 APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: I L 116 v-r•-t_ z/a sl t c/ 4\ \.(t) Pr* .n3 0K:t. - 2n18 (» /4:2*//5 A2-27 74..; Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Alaska Oil and Gas Conservation Commission 3333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Application for Sundry Approval (10-403) February 26, 2018 To Whom it May Concern: Attached please find the Sundry Application for Set CIBP and Perforate for well PBU P-06B, PTD #205-138. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachments: Form 10-403 Current Wellbore Schematic Detailed Statement of Requirements Proposed Wellbore Schematic Mini-log TREE= 4-1/16"CNV 0 I 1 NOTES:142S READINGS AVERAGE 125 ppm WELLFEAD= 5M FMC I ACTUATOR= OTIS P-06B W ON MI.WELL REQUIRES A SSSV WHEN ON ML ORIGINAL WELL(P-06)IS NOT SHOWN ON KB.ELEV= 77.90' DIAGRAM.""4-1/2 CI-ROME TBG***WELL ANGLE> BF.ELEV= 55.41' I 70° 10185'. KCP= Max Angle= 103°@ 10573' • %`, 2103' —4 GAS1/2"UFTOTISmASSaDRELSV NPs,ID=3.813 Datum ND= 9964' ' Datum 1-VD= 8800'SS ST 1.4) VD DEV TYPE VLV LATCH PORT DATE 10-3/4"CSG,45.5#,NT-80,ID=9.950" — 2687' 5 2985 2985 0 CAMCO 'DMY BK 0 05/27/16 4 5514 5481 24 CAMCO 'DMY BK 0 05/27/16 3 7729 7224 39 CAMCO 'DMY BK 0 05/27/16 2 9267 8389 43 CAMCO *DAY BK 0 105/27/16 Minimum ID = 2.37" @ 10909' 1 9636 8654 44 CAMCO **MY BK 0 104/18/04 TOP OF 2-718" LNR .STA#2,#3,,#4,&05 DMYS HAVE FRUEINMERG PACKING "MANDRI3_COVERED sr MBA ENT(10/20/05(IMS) 1' /4 9647' —3.70"DEPLOY SLV,ID=3,00" I 0 / 0 0 - P. 9664' —4-1/2"PKR SWS NP,U' 3.813"(BEHIND PIPE) ] 'I '1 11 /4 9666 —3-1/2"HES X NAP,D=2.813" , I, M 1 9677' —7-5/8"X 4-1/2"71W1-18BP PKR(BlaIN)PIPE) I I ' 3-1/2"LNR,8.81#,L-80 STL, .0087 bpf,D=2.990" H 9699' P;4 9699' —3-1/2"X 3-3/16"XO,ID=2.867"4 o .4 4, — 9709' —4-1/2"PKR SWS NP,D=3.813" • 14 1 r 9731' —4-1/2"PKR SWN NP,MLLED TO 3.80' BEI-UND ITOP OF 5-1/2"L — —9739' 1 A CT LNR I NP, 11 * 9739' 1—7-5/8"X 5-1/2"11W LNR HGR VVITBS • 11 It 0 4-1/2"TBG, 12.6#,13-CR,0152 bpf,ID=3.958" —1 9742' • 14 11 *1 9743' —4-1/2'WLEG,D=3.958' Ov* Ivc NOTE TAILPIPE HAS BACI033 OFF& 41 *4 1* 1* IS RESTING ON 5-112"LNR TOP ,•1 *4 & 7-5/8"CSG,29.7#,NT-95-FIS,ID=6.875" — 9966' FA .. 44 4 ,..-...,'‘, W1PSTOCK(10/13/05) H 9974' ELM MILLOUT VANDOVV(P-06B) 9974'-9982' 'ffrfrf* .*****... r,......... .4iiirA„..4 10909' H3-3116-X 2-7/8”XO,ID=2.441" 11 Vs.& PERFORATION SUM.%RY 3-3/16"LNR, 11450' 2-7/8"CIPB 6.2#,L-80 TCI, — 10909' I \ • (09/21/10) REF LOG: WAYEWR/SGRC/SROP ON 10/25/05 0076 bpf, 1)=2.80" - \ ANGLE AT TOP MT:80°@ 10925' Note'Refer to Production DB for historical perf data SEE f SPF INTERVAL Opn/Sqz [ATE Pi3TD ---1 11561' 2" 6 10925- 11050 0 10/27/05 2" 6 11490- 11530 C 10/27/05 I, 3.70"BKR REIRIEV A LBE BP w/SUPPORT FIFE TO 7D —1 11596' .fr•'__. 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,ID=2.441"— 11597' ... TD — 11800' DATE REV BY COM DATE REV BY COMENTS PRUDHOE BAY UNIT 05/23/91 SJA ORIGINAL COMPLETION 04/22/12 RCT/PJC SET PX PLUG(4/18/12) WELL: P-06B 12/25/97 PARKER CTD SIDETRACK(P-06A) 06/05/12 RT/JM) IDU_LED PX PLUG(06/01/12) REKNIT No:02051380 10/29/05 NORD1C1 CTD SIDETRACK(P-068) 05/31/16 JAR/JM.) GLV C/O(051127/16) AF1No: 50-029-22166-02 09/22/10 SFB/PJC SET CP(09/21/10) SEC 31,T11N,R13E,2506'FSL&1963'FWL 02/10/11 A43/.1M) ADDED SSSV SAFETY NOTE 01/18/12 TIANYJMD'A COEID H2S SAFETY NOTE BP Exploration(Alaska) • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0, DBR, LHD,EAZ, BGG 10/12/15) General Information Well Name: P-06B Well Type: WAG Injection Well API Number: 50-029-22166-02 Well Activity Conventional 4 Classification: Activity Description: Plug&Add Perf Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IV!SHAK 12 Month Avg IOR, 30 bopd: Job Type: Add Perf+WSO-Plug Estimated Cost, $30 $K: AWGRS Job Scope: PERFORATING • Other regulatory None requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Yes PrimarySecondary Required? Engineer: Travis Alatalo Contact numbers: (907)564-5351 (907)378-3949 Well Intervention Engineer: Ryan Thompson Contact numbers: (907)564-4535 (907)301-1240 Lead Engineer: Laurie Derrick Contact numbers: (907) 564-5952 (720)308-3386 Date Created: February 7, 2018 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Date Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injection (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Pressure Cut(%) (Mscf/Day) (psi) 2/5/2018 4,271 0 984 Current Status: Operable Flowing Inclination>70°at Depth(ft) 10,185' MD Recent H2S (date, ppm) NA 0 ppm ✓ Maximum Deviation(Angle and 10.573'MD Depth) Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 27° 10.249'MD Reservoir pressure(date, 7/21/2006 3.307 psi Minimum ID and Depth 2 370" 10.909'MD psig) Reservoir Temp, F 214° F Shut-in Wellhead Pressure 179 psi Known mech. integrity AA for PWI only. IA repressurization on MI problems(specifics) Last downhole operation(date,operation) 5/27/2016 Gas lift integrity-swapped valves 2-5 Most recent TD tag(date,depth, toolstring OD) 8/22/2010 10141 SL Drift to deviation w/10'x 2.50"dmy gun &sample bailer Surface Kit Fit-for-Service? YES If No,Why? If well has been shut in for> 1 year or job cost>$500M. fill out Non Rig Surface Equipment Checklist Comments,well history, P-06B was CT ST in October 2005 and pre-produced until July 2006. Prior to putting the well on injection background information, the well locked up during a MIT-IA to 2500 psi and had no injectivity on the tubing either. CT removed ice etc: plugs from 278'. 402'and 1743' MD then acidized the perforations with DAD acid: the injectivity improved to 1.4 bpm at 1865 psi In March 2007 the well was given an AA for PWI only. in September 2008 dummy GLVs with extended packing were installed in stations 2. and 3 and the well passed a MIT-IA to 2500 psi While on water injection. an E-Line Tractor conveyed !PROF determined that the 87%of fluid was going into the toe perfs. In April 2009 the well was placed on MI injection for evaluation and the AA was removed in November 2009. The E-Line Tractor returned in August 2010 to set a CIBP at 11.450'MD to isolate the toe perfs. The well returned to MI injection in June 2011 and IA repressurization was again observed. diagnostics on the well head determined that communication was occuring through the well head seals • • when the PPPOT-T failed on April 09,2012,the LPE determined that the primary seals were bad and the secondary seals appeared to be holding. On May 23,2012 Sealtite was pumped into the void and repaired the IA repressurization. Brightwater was pumped in May 2014 and offset producer P-11 had a lateral added in April 2015. In May 2016 the GL valves were swapped once again and IA repressurization was observed when injecting MI.A second AA was approved for PWI in August 2016. The objective of this program is to isolate the existing perfs in P-06B and add perfs closer to the parent bore. None of the historical injection in this well can be seen benefiting offset producers.We will keep the well on PWI until further diagnostics are run to repair IA repressurization while the well is on MI. • • • Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. 3.Does the planned equipment to be installed in the well meet the requirements of the GWO Well Equipment Group Practice,GP 100220(AKA 10-50),by either being documented as Legacy Equipment or having the required design assurance work completed?https://gwo.bpglobal.com/sites/gwo2/GlobalLibrary/100220.pdf Suspected Well Problem: Injection not supporting offset producers. Specific Intervention or Well Objectives: 1 Set plug to isolate current perfs and add perfs in the heel. 2 3 Key risks,critical issues: Mitigation plan: 1 We have not drifted to deviation since 08/2010. Drift w/SL prior to setting plug and perforating. Brush and flush if necessary. 2 Cost saving opportunity w/perf guns. Use BP owned 2.5" PowerJet Omega guns. 3 Plug and Perforating depths are around deviation Use pump down or rollers at EL WSL discretion to assist getting to proposed depths. Min ID above new perforations is 2.786"(see liner tally), 4 swell on the 2.5" PJO's is 2.78". Run jars with perf assembly Summary Step# Activity 1 SL Pull MCX. Drift to deviation WI dmy guns. 2 EL Set plug. Add perfs 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 SL Pull MCX. Drift to deviation w!dmy guns (discuss drift with EL WSL to verify if running roller stem is a viable option) Set CIBP @ deviation in the 3 3/16"liner(ideally around 10.250'MD) Add perfs according to attached perforating form. A Recommend running jars with perf assembly to mitigate any issues pulling guns back through 2.786" XO @ 9699' MD. 2 EL B. Plug/Perforations are both near deviation. Use rollers or pump down if necessary to get to depth. (last SL drift deviated out at 10.141 SLMD on 8/22/10) C. Set CIBP as deep as possible near deviation staying below new perforation interval Stay 2-3'away from collars. 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: NA MMSCFD: NA BWPD: NA Expected Production Rates: — FTP(psi): NA Choke setting: NA PI(bfpd/psi dp) Post job POP instructions: Turn over to DSO. POI @ 3000 bopd injection target. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form, logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc • • ...i"- PENDING PERFORATING PROCEDURE RD" u.,..n Well: P-06B API6:50-029-22166-02 p''� Date 217/2018 Prod Engr Travis Alatalo Office Ph: (907)564-5351 P H2S Level: Home Ph: 0 ppm Cell/Pager: (907)378-3949 CC or AFE: APBINJEC W BL Entries IOR TZpe_--._,Work Description_.___ I See Procedure Well Objectives and Perforating Notes: Perform 2 full gun runs with top charge©10,087'MD. Use BP owned 2.5"PowerJet Omega HMX Guns Attachment: Tie-in log with proposed perfs annotated Reference Log Tle in Log Add 0 feet Log: _WR D/GR/EWMWD/GR/EWR_ to the[ie-in log to be on Date: 10/25/2005 10/25/2005depth with the reference log. Company: Halliburton Halliburton Depths(from-to) Depths(from-to) Feet SPF Orient. Phasing Zone Ad/Reliperf 10,08T 10 149' _-10,O8T 10149 . 62 6 Random 60' 48 Adperf Requested Gun Size: 2-1/2" Charge: 2506 PJ Omega HMX Min Wellbore ID: 2.786" Mao Swell In Liquid: 2.78_ Mae Swell In Gas: NNR Is Drawdown Necessary/Desired/Unnecessary During Perforating Unnecessary__ Preferred Amount of Drawdown/Suggestions to Achieve Drawdown ------ Last Drift: _10141 SL ft MD on _8/22/2010 Est Res.Pres.@ 8,800'TVDss MD is 3307 psi Perforation Summary Well: Pdsa Town: Date: API 9: 50-029-22166-02 Prod Engr. •Anch Prod Engr P.D.Center PBTD ---- ----- - General Comments: -----'- Depths Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf 0/B/U - 0/B/U - 0/B/U .._ ___....- 0/8/U - 0/B/U - 0/B/U - 0/B/U - _-- 0/B/U 0/B/U !- 0 • HALUBURTON DGR Dual Gamma Ray EWR Electromagnetic Wave Resistivity ROP Rate of PenetrMion 11i Pms.wil INSITE Horizontal Presentation i im IIIMINIENNElli I 2 : 2 7 5 5 3 5 ! 1 1 . 600 / 1 : 240 Sperry Drilling Services i 1 i . I , Company : BP Exploration (Alaska) Inc. Rig : Nordic 1 Well : P-06B Z r . 1 o I .s Field ' Prudhoe Bay c,c VV. P , 1 r: ci S 1 : kr12 ie g 18 Country : USA E l' . 1 - API Number -. 50-029-22166-02 A a II , ii g f . :A z:§ u.. . _ . . . . ... -----,-- .... , z Latitude :70°15 50.1r North 8 I Other Services longitude:148°56' 19.94"West I1,. i 1 * AK STATE PLANE ZN 4 X= 631,246(X)Et ' AK STATE PLANE ZN 4 Y=5,947,233,00 FT i1 Permanent Datum Mean Sea Level Elevation: 0.00 ft Elev. Ke 92.10 ft Log Measured From Gamma Ray Tie In 0.00 ft Above Permanent Datum OF 0.00 ft GL 0.00 ft Drilling Measured From . Gamma Ray Tie In MD LOG WD 0.00 ft Depth Logged 9,994.00 ft To 11,800.00 ft Unit No 109 Job No. :AK-MW-0604005436 Date Logged : 22-Oct-05 To 25-Oct-05 Total Depth MD : 11,800.00 ft TVD 8,940,97 ft Plot Type: Final Spud Date : 22-Oct-05 Plot Dale : 14-Aug-07 SoitholeRtcogl ri :...-iirkflorgUel Run No — Run No. To 4250 in 9.984.00 ft 11.800,00 it - Size.. Dora .1 To I Cars bard(lit0J, -----ke-- Were i From To =111111111111111111111 ;'sr :::,, — . 'z.4 t. i : • s • i ,-.Z.A25,in i18 le wi .SLIBEAcg_i_.94Wor.1 - ._...1Q,iw on 5 lb.. i„iiitt-Ach ,w I 1 • 1 :240 MD Horizontal Presentation SFXE 0.2 hours 2000 SEXP ohrii-nt 2000 SEW 0.2 2000 SROP SEMP i000 feet per hr 0 0.2 tohm-m 2000 SGRC SEDP TVDss MD 15.0 4 150 api 300 02 °hymn IWO 9000 ft 8900 • • _ ---- . 11111 Assmr" -1- .`-'e 3123 <BEGIN RUN'> - r — h---- ',:rt , la= L.... 1 _ _�` BOTTOM O�W��l?S�OCFC it X34'ASD.$814 TJt]sc C---- __.__— q . 4 arr'�� .Y -1 1111111111111.111110M1 -, -- elf I -----4 -. , 10100 - t_.. , _ '" 1 _ Adperf +t 10,087'to 10,149' 1 .----/ ._..e...7 ' ...rte. 7_...... _...._ __...._.--d-- e.- r r �+a-�___� �f .. A-_.._-__,__�. ,I. _ -_.... • • • _.1 4 . 1 1 -- ----� 3 t M ; i _ .__„I • S- ....: f c...__3 "r f 10200 ' I - -- 1 3 t i I t ..__. Set plug at —__. ---t I - deviation ideally — 4 _. around 10,250', --- adjust depth to — — avoid setting in ' �_ _ collars I --, , t --- -__]____ i t 10306 IMONIMINNIMMUMMilr 4 • i 1 'T ---f- III S oNERbp LINER/CEMENTING SUMMARY DATE ( October 13,NW WELL#P-068 SIZE/WT/FT I GRADE/THREAD 1132.875 6.16 L-80 STL 2441 in 3.188 610 1-80 TC fl 2800 in 3.500 8.81 1-80 STL 2.992 in BOTTOM OF UNER AT 11,800.00 ft TOP OF LINER AT 9,64723 ft TOP OF KB LINER TOP PACKER AT ITEM Description includes: SIZE,TYPE,CONNECTION NO ITEM 00 IC LENGTH TOP BOTTOM 2-7/8"30 Biased Indexing Shoe 2-875 2.380 1.63 ft 11,798.37 11,800.00 6 2-7/8-8.18#Ift L-S0 STL Tbg w/Turbos 2.875 2.441 190.31 ft 11,608.08 11,798.37 2-3/8-3Rd Box X 2-7/8"STL Pin XO 3.070 2.440 0.41 ft 11,607.65 11,608.08 BOT Retrievable Bridge Plug 3.700 3.000 10.75 ft 11,596.90 11,607.65 2-7/8"STL Biased Indexing Shoe 2.875 2.380 1.63 ft 11,598.27 11.596.90 2-78'STL Float Collar 2.040 2.380 0.80 ft 11,594.47 11,59527 1 2-7/8"6.18#/3 L-90 STL Tbg in/Turbo 2.875 2.441 31.78 ft 11.56289 11,594.47 2-7/8-STL Flan Collar 2.940 2.380 0.80 ft 11561.89 11,58209 2-7r8"STL Landing Collar 2.875 2.250 0.80 ft 11,561.09 11,561.89 20 2-7/8'C.1641/11 L-80 STL Tbg art Turbos 2.875 2.441 832.99 3 10,928.10 11,581.09 M81 TD LSL SuA4 XO 3-3116-TCII X 2-778"STL Pen 3.500 2377" 19.28 3 10,908.82 10,928.10 39 3-3(18"8.2#/ft L-80 TC1l liner with 3.7"Turbos 3.400 2.800 1208.36 ft 9,700.48 10,908.82 3-1.,2"STL Box X 3-3118"TCII Pin XO 3.400 2786" 1.55 3 9,598.91 9.700.48 1 3-112'9.81 Wft L-80 SP Liner via turbos 3.500 2.992" 31.44 3 9,667.47 9.488.91 HOWCO"X"11ppEe 113.7-OD el 3.313'Proffe) 3.700 2.813 1.00 ft 9,666 47 9,867.47 3-1/2`8.81#/111_40 STL Pup Joint 3.700 2.992" 9.75 ft 9,858.72 9,666.47 i-1i 2'8.81It/R L-80 3T1 Pup Joint 3.700 2992" 3.73 ft 9,552.03 9,858.72 BOT liner Depiaynaent Sleeve 3.700 3.000 5.78 ft 9,64723 9.852.99 67 its Note: Turboicementroli-.er 1engtis are incl on a7 @ants BMA Total Length ► 2152.77 **CORRECTIONS MADE BY T.HOLBROOK 1207/75 I S TREE 4-1;1W ENV sAr-el I'NOTES 142-5 14,46.18G6 A V ETRA ti'Ac..17$ppm 'IAIELLHEAD %AMC A.C111ATOR 011S P-06 B „„,,..0.si.w,-,„ htt_Q.144ti..:t3 4 4400/WHEN ON *I I.01411011441 wtH t ip-oki is Aral 141414404 ON .KB EL.Ev 77 90' 134A6440414.""'4.-1,2-ONNOM-.I.1 BG-VVEL L 41413t.F.,. ar a..o,- 5541' . ,KOP= 4940 .A.44.4 Ang44 7- 7 = 10.3.-0'mil I 921: 71 4 ler OTIS EISE,I.V ImP,63-3 613 lulu-A ur)=•••• EKr54. - C) 13441 TV D= 9030SS GAS UFT MANUAL:LS _-___. 1.10-aft.Cs..1-,.,46 54,NT-80.41..A X.50.' --1, burr -- ST; MD TVD I30/1 TYR VLV JTQ1 PORT1 04TE -.---7296s. 29815 0 ICA6-400 13646' BK. 0 i 05,2716 1-1 4 15514 5461 24 I GOMM -our Eirr, 0 /05a27f16 3 7779 7224 39 I CAW:0 'DPW BK 0 105(27+16 Minimum ID 2.37"1§ 10909" 2 ,9267,9309 43 ICANCO TOM Eid4. 1 0 105427416 1 i 9639 1.95.4,, 44 I CAN6X3 -ELK BK_1 0 ,i0618104 TOP OF 2-7,6' LNR -stA tn.114,114,&06-curt'HAVEARILJEDEIMINERG PACFING --- -- -- 14A011203.COVERED r(013101442T(14(2006 01610 4647" --I 1171.14,LOY 5LV,LI Nite.r. 1 I . i 100641 I-1444"MM$IAS NC.0=3 BIT"(00400 01Pa I 0 I 10064r Ha-1,7"ME.X tdp,ry.•;,gia. . , 1 :awn' r_13_7 MS:a.X 4 1 3 3,T6..70:011@tAr, piosr,,MU.4 0117:77677 / !3-i Or 1_14M.Ft AIX,1_-(50 511.... 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FA:MONA maks 51,144MARY .3-3i1W LANT.,6.28,1-80 TUE --- lovoir I 11450 -2-7:6"OPE3 PET'LOG.INAGELINTAISGFC/SROP ON 102S*05 0079 bill.El-2 SW 1 .{crar2ttio) Awit±Al TT4'11141- 0(14 a 141542V 14344./4.04,to Ftts664:1mrt 139 for teltImma4 pee 0444 WE SFT NORVAL OpniSt4.4 DATE ;Ht6Itt+ - 11Se1 att_ . 21 6 16061 6 11211 0 141121705 .—.. ........_... .- Tett'EWA M.THIPS A LSE tIP vt raf.FPCIFII Mir.14..1 TD 1- 115961 j 2" 6 11490 115M C 102705 [ [2-1i6-LA414,6 I64.L 80 St.,.0868 bpe,43-2 442j 11 ser ..,, ----- -- /131.--1 11000 ' OA 11- 1 (V4(13Y 1 COMPALIOS ' UAW 1 few BY I OCMANENTS 1.14.4914)1.SAY U41 I 06123J4t t SA 00110004L CONIPLETION 04,22112 1CTS RIC rOET 13/4 Pt LIG 44'104171 M1,- P0613 12138e87: PAG 'CIO 9111E0110141((P41644.) 06126,12 I RKV,1410 PIA 1 ED Plc PI 1401064,111,12) 14-41141-1*-"2051360 10129196 i NOMEOCT[CYO ONIETIALIACK(P-064111 06431(16 1 JA46.44)(2.V 0'0 0627:161 AN N:: 5&3-O29-2214 - 2 0602200 I SPEVRE I SET OPP 4410214110) 4 .11(44::14 41 IN.P1:14.2600 4-$4,14 1913 411141. 02/10111 14:11.441O1ADOEDSSSV SAFETY • g 01 T)414.60 I ADIITHOS SAFElY 1431F "la`12.1_ AP ExpAmation(Alostoil • S wrmrmr , 0-50134 L'3 NN,tN 0 0 14.1 (1.R3i)Oh o N 1a,6�,,,r,t,in„Inap 41.4/,m•.r 7,4,,4".1...tIt, ,.1.ni ,.(t,,,,r,,,,I,,.,,,..fr„rho 0)W O,D N 0)'0°"T-rz0DO• 0),v t0 O H W N 0)O M 0) N (D0).D(N (13 34)6"11°."(N^,0)'0•'.co 0'0)L r-N O0)0 C0 C)(0 0 N N N (N C,O,CO C 0)0)0)0)0)0)CO OHGL,C70)0)0)0CO07 CO O,CO 0,0,0+0, tT P O. 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I • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, October 06, 2016 6:59 AM To: AK, OPS GC1 OSM;AK, OPS GC1 Field O&M IL;AK, OPS GC1 Facility OIL;AK, OPS GC1 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead;AK, OPS Well Pad YP;Alatalo,Travis; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington,Aras J Subject: OPERABLE:Injector P-06B (PTD#2051380)Administrative Approval AIO 36.005 for Water Only Injection Attachments: P-06B AA AIO3B.005 10-05-16.pdf All, Injector P-06B(PTD#2051380)was classified as Not Operable on 08/27/16, due to Tubing x Inner Annulus communication while on miscible injection (Ml).On 09/30/16,the AOGCC granted Administrative Approval,AIO 3B.005, allowing water injection only, subject to conditions specified in the attached AA. The well is reclassified as Operable,and may be brought online in water only injection service as required. Please be aware of the fluid-packed annuli. • Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) :(907)659-5102 CO:(907)943-0296 s`ptiNED FEB 2 7 2-017, H:2376 Email: AKDCWellIntegrityCoordinator@BP.com From: AK, GWO . ' Well Integrity Sent: Saturday, August , 016 4:11 PM To: AK, GWO Well Integrity We • ormation; AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS • •_ ontrollers; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Special Projects; AK, GWO SUPT Slickline; AK, RES GPB West Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace . a.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well In - ; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Worthington, Jessica; Dickerman, Eric; Munk, Corey; 'Regg, James r. 'OA); Glasheen, Brian P; Pettus, Whitney; AK, GWO Completions Well Integrity; AK, GWO Well Integrity Well Informatio Subject: NOT OPERABLE: Injector P-06B (PTD #2051380) Inner Annulus Repre ization when on MI All, • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday,August 27, 2016 4:11 PM To: AK, GWO Well Integrity Well Information;AK, OPS GC1 OSM;AK, OPS GC1 Field O&M TL;AK, OPS GC1 Facility OTL;AK, OPS GC1 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Special Projects;AK, GWO SUPT Slickline;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead;AK, OPS Well Pad YP;Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R;Worthington,Jessica; Dickerman, Eric; Munk, Corey; Regg, James B (DOA);Glasheen, Brian P; Pettus,Whitney;AK, GWO Completions Well Integrity; AK, GWO Well Integrity Well Information Subject: NOT OPERABLE:Injector P-06B (PTD#2051380)Inner Annulus Repressurization when on MI All, Injector P-06B(PTD#2051380)was put on MI injection as Under Evaluation on 08/02/16 to monitor signs of TxIA communication. After monitoring for 25 days, annulus pressure trends indicate TxIA communication when on MI injection. Considering recent passing pressure tests and absence of TxIA communication while on water injection, BP will apply for an Administrative Approval for water injection only. This well is now reclassified as Not Operable. Plan Forward: 1. Downhole Diagnostics: Bleed IA—DONE 04/16/16 2. Downhole Diagnostics: Monitor IA pressure—DONE BUR"'45 psi/day 3. Wellhead: Perform PPPOT-T—PASSED 4/18/16 4. Fullbore Pumping: MITIA—PASSED to 2500 psi 5/1/15 5. Downhole Diagnostics: Monitor IA pressure-DONE 0 psi/day 6. Slickline: Change out dummy gas lift valves—DONE 5/27/16 7. Fullbore: MIT-IA—PASSED to 2250 psi-05/27/16 8. Operations: Put on Injection—Use caution, liquid packed annulus-8/2/16 9. Downhole Diagnostics: Monitor IA pressure—8/27/16 10. Well Integrity Engineer:Apply for AA for water injection only—In Progress Please call with questions or concerns. Thanks! Jack Lau (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent GW Ux�csty .,_; W: 907.659.5102 C: 907.943.0296 H:x2376 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Sent: Tuesday,August 02, 2016 7:04 AM To: AK, GWO SUPT Well Integrity;AK, OPS GC1 OSM;AK, OPS GC1 Field O&M TL;AK, OPS GO. Facility OTL;AK, OPS GC1 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Special Projects;AK, GWO SUPT Slickline;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead;AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers,Jessica; Dickerman, Eric; Munk, Corey; Regg,James B (DOA); Glasheen, Brian P Subject: UNDER EVALUATION:Injector P-06B (PTD#2051380)Inner Annulus Repressurization All, Injector P-06B (PTD#2051380)surface work has been completed and the well is operationally ready to be placed on injection.The well is now classified as Under Evaluation and will be monitored for up to 28 days while online for signs of TxIA communication. Plan Forward: 1. Downhole Diagnostics: Bleed IA—DONE 04/16/16 2. Downhole Diagnostics: Monitor IA pressure—DONE BUR^'45 psi/day 3. Wellhead: Perform PPPOT-T—PASSED 4/18/16 4. Fullbore Pumping: MITIA—PASSED to 2500 psi 5/1/15 5. Downhole Diagnostics: Monitor IA pressure- DONE 0 psi/day 6. Slickline: Change out dummy gas lift valves—DONE 5/27/16 7. Fullbore: MIT-IA—PASSED to 2250 psi 05/27/16 8. Operations: Put on Injection—Use caution, liquid packed annulus 9. Downhole Diagnostics: Monitor IA pressure 10. Well Integrity Engineer: Evaluate for AA Please call with questions or concerns. Ryan Holt E� %AMU OC �1 BP Alaska-Well Integrity Office: 907.659.5102 From: ' , '&C Well Integrity Coordinator Sent: Monday, .-- 16 2016 12:42 PM To: AK, OPS GC1 OSM; AK, •• • O&M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; ' ' , . • SUPT Special Projects; AK, GWO SUPT Slickline; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; ' ', :• •CC Ops Lead; AK, OPS Well Pad YP; Odom, Kristine; 'ch ris.wa llace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, OPS F ! • ••s Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Munk, Corey; 'Regg, James B (DO' , lasheen, Brian P Subject: NOT OPERABLE: Injector P-06B (PTD #2051380) Inner Annulus Repressurization 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, June 06, 2016 12:42 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL;AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Munk, Corey; Regg, James B (DOA); Glasheen, Brian P Subject: NOT OPERABLE:Injector P-06B (PTD #2051380)Inner Annulus Repressurization All, Due to surface restraints Injector P-06B (PTD#2051380) has not been put on injection to evaluate Inner Annulus repressurization. This well is now reclassified as Not Operable. The well will be revaluated for Inner Annulus repressurization once surface work is complete and the well is ready to be put on injection. Please respond if in conflict with the plan forward. Jack Lau (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent W: 907.564.5102 C: 907.943.0296 H: x2376 From. A K, D&C Well Integrity Coordinator Sent: Th day, May 12, 2016 6:12 AM To: AK, OPS • M; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, • : • Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, ' - GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; AK, OPS Well Pad YP; Odom, Kr • e; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; • D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, ica; Dickerman, Eric; Munk, Corey; Regg, James B (DOA) (jim.regg@alaska.gov); Glasheen, Brian P Subject: UPDATE: UNDER EVALUATION: Injector P-06B • D #2051380) Inner Annulus Repressurization All, Injector P-06 (PTD#2051380) had begun showing anomalous inner annulus (IA) repre rization when shut in in April 2016.The well passed an MIT-IA to 4000 psi on 27'h August 2015, confirming two compete wellbore barriers, and was placed on miscible injection in November 2015.The well had been reclassified as Under Evalua ••n on April 16, 2016 and remained shut in for diagnostics. IA build up rates was—45 psi/day post bleed while shut in. A PP•• -T passed on April 182016 and an MITIA passed to 2500 psi on May 1 2016. The IA build up rate post-MITIA was 0 psi. Du- o surface work constraints Operations will wait to late May to put on injection for additional diagnostics. The plan forwar. • to add 28 days to the Under Evaluation period to POI, monitor IA pressure, and evaluate for AA. 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, May 12, 2016 6:12 AM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; AK, OPS Well Pad YP; Odom, Kristine;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Munk, Corey; Regg, James B (DOA); Glasheen, Brian P Subject: UPDATE: UNDER EVALUATION:Injector P-06B (PTD #2051380) Inner Annulus Repressurization Attachments: Injector P-06B (PTD #2051380)TIO and Injection Plots.docx schielEV NAY 1 7 t.0 1b All, Injector P-06 (PTD#2051380) had begun showing anomalous inner annulus (IA) repressurization when shut in in April 2016.The well passed an MIT-IA to 4000 psi on 27th August 2015, confirming two competent wellbore barriers, and was placed on miscible injection in November 2015.The well had been reclassified as Under Evaluation on April 16, 2016 and remained shut in for diagnostics. IA build up rates was—45 psi/day post bleed while shut in. A PPPOT-T passed on April 182016 and an MITIA passed to 2500 psi on May 1 2016. The IA build up rate post-MITIA was 0 psi. Due to surface work constraints Operations will wait to late May to put on injection for additional diagnostics. The plan forward is to add 28 days to the Under Evaluation period to POI, monitor IA pressure, and evaluate for AA. Plan Forward: 1. Downhole Diagnostics: Bleed IA—DONE 04/16/16 2. Downhole Diagnostics: Monitor IA pressure—DONE BUR —45 psi/day 3. Wellhead: Perform PPPOT-T—PASSED 4/18/16 4. Fullbore Pumping: MITIA—PASSED to 2500 psi 5/1/15 5. Downhole Diagnostics: Monitor IA pressure - DONE 0 psi/day 6. Operations: Put on Injection 7. Downhole Diagnostics: Monitor IA pressure 8. Well Integrity Engineer: Evaluate for AA A copy of the TIO and injection plot has been included for reference. Please reply if in conflict with proposed plan. Thank You, Jack Lau (Alternate.)Adrienne McVey BP Alaska-Well Integrity Superintendent W: 907.564.5102 1 • • Injector P-06B (PTD#2051380) TIO Plot May 12, 2016 Well P-06 4.000r 3.000 i Tbg -f-IA 2 000- -,46-OA OOA 1000• -4--000A on— • 03'12'16 03!9'16 0326'16 04'0216 04+09.'16 04'1616 042316 03'30'16 0507116 Injection Plot May 12, 2016 Well P-06 -2.500 -2.000 -1NHIP Sof 1300' . 1'500 1.036 -1.000 -GI -Other 500- -500 -On 031216 03.1916 032616 040216 040916 041616 002316 34?5,6 :"1€ • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, April 16, 2016 9:01 PM To: AK, OPS GC1 OSM;AK, OPS GC1 Field O&M TL;AK, OPS GC1 Facility OTL;AK, OPS GC1 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead; AK, OPS Well Pad YP; Odom, Kristine; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Munk, Corey; Regg, James B (DOA); Glasheen, Brian P Subject: UNDER EVALUATION:Injector P-06B (PTD #2051380)Inner Annulus Repressurization Attachments: P-06B (PTD #2051380) TIO and Injection Plot.docx;Injector P-06B (PTD #2051380) TIO and Injection Plot.docx All, Injector P-06 (PTD#2051380) has recently begun showing anomalous inner annulus (IA) repressurization when shut in. The well passed an MIT-IA to 4000 psi on 27th August 2015, confirming two competent wellbore barriers, and was placed on miscible injection in November 2015.The well has been reclassified as Under Evaluation, and should remain shut in until diagnostics are complete. Plan Forward: 1. Downhole Diagnostics: Bleed IA—DONE 04/16/16 2. Downhole Diagnostics: Monitor IA pressure for 3 to 5 days 3. Wellhead: Perform PPPOT-T SCAIWED APR 1 8 20$4. Well Integrity Engineer:Additional diagnostics as needed A copy of the TIO and injection plot has been included for reference. Thanks, Adrienne McVey (Alternate:Jack Lau) BP Alaska-Well Integrity Superintendent G WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator(a)BP.com From: AK, D&C Well irftegrity Coordinator Sent: Tuesday, July 03, 2012 8:23 PM To: Regg, James B (DOA); 'Schwartz, Guy L (DOA)'; C1 OSM; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Facility OTL; AK, OPS Well Pad YP; Cismoski, Doug k AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Optn ;$K, OPS Prod Controllers; Brown, Don L.; Daniel, Ryan \` 1 •• • Injector P-06B(PTD#2051380) TIO Plot 2016/04/16 Well F. OA 004 00a ✓' 0,16+6 017316 01.4.1R :,l,o,E ?1'.,!E Cat2 f WI 16 GI'6 Injection Plot Well P06 3400- r 15.000 3.300• l 3200 -14000 3.100 3.0000• 2.900. -13006 2.800• 2.706 -12 000 2.600 2500' -11000 2400• 23 0. -10.000 2200' 2 100 -9 000 2.000 -WI0P 1906 -8000 -9W{ c 1800 Ay 100. M 1.600• -7000 - 1.500• -0184, 1.400 -6 ODD 46 1.300 1.200' -0000 1 100• 1 000 900' -4000 800' 7 -3000 600• -2000 300 200. -1.000 100 0113,16 010316 015016 020616 02'1116 0200'16 0227,16 0305'16 0312116 0319'16 032616 0402-16 0405'16 04-1616 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original fife, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q ~- ~ ~ ~ Well History File Identifier Organizing tdone) RE AN Color Items: ~Greyscale Items: ^ Poor Quality Originals: ^ Other: .e=.d~ iiumiiiuiuiiii DIGITAL DATA ~iskettes, No. ^ Other, No/Type: aeua~~e~ea iuuiiiiiiiuuii OVERSIZED (Scannable) ^ Maps: ^ Other items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ©g /s/ ' Project Proofing III II IIII II III II III BY: Maria Date: ~, ~ /s/ Scanning Preparation ~ x 30 = ~ + ~ =TOTAL PAGES (Count does not. include cover sheet) BY: Maria Date: ~ ~ $ /s/ / Production Scanning III IIIIII IIIII II III Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Mari Date: a,~ ~ O V Jsl ~V ~/ I,p 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II II II III II I ~ III ReScanned III IIIIIIIIII) II III BY: Maria Date: /s/ Comments about this file: o ~ ~.~kea iuiuuuuumii 10!6!2005 Well History File Cover Page.doc STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMMI. iN ` REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 11 Repair Welt] Plug Perforations ❑ PerforateU Othe] Bright Water Performed: Alter Casing❑ Pull TubinJ Stimulate-Frac ❑ Waiver Time Extensia❑ Change Approved Program❑ Operat.Shutdowi❑ Stimulate-Other ❑ Re-enter Suspended We❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc DevelopmenC Exploratory❑ 205-138-0 3.Address: P.O.Box 196612 Stratigraphi❑ Service El 6.API Number: Anchorage,AK 99519-6612 50-029-22166-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028288 PBU P-06B ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECIVED Total Depth measured 11800 feet Plugs measured 11450 feet true vertical 9033.06 feet Junk measured None feet J`U N 1 8 2O 14 Effective Depth measured 11450 feet Packer measured 9677 feet G CC true vertical 9031.24 feet true vertical 8683.2 feet q� Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 37-117 37-117 Surface 2648 10-3/4"45.5#N-80 39-2687 39-2686.98 5210 2480 Intermediate 9930 7-5/8"29.7#L-80 37-9967 37-8893.31 6890 4790 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10925-11050 feet 11490-11530 feet True Vertical depth 8999.37-9024.33 feet 9028.4-9025.45 feet SCANNED J U L 1 0 2014 4 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 34--9744 34-8731.55 Packers and SSSV(type,measured and true vertical depth) 8683.2 9677 8683.2 Packer 2102.99 2103 2102.99 SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10925'-11050' Treatment descriptions including volumes used and final pressure: 1196 Gallons EC9360A Surfactent,5750 Gallons EC9398A Polymer,2134 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 3446 0 1981 Subsequent to operation: 0 0 2574 0 1370 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Explorator❑ Development] Service Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSP❑ iGSTOR ❑ WINJ ❑ WAG 0 GINJ❑ SUSP ❑ SPLUC 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: N/A Contact Garry Catron Email Garry.Catrona.BP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date 6/18/2014 v'-c ��c / 1.4 RBDMS JUN 19 2014 /9/ Form 10-404 Revised 10/2012 Submit Original Only • lid � co 00030 co NN' 0 o O c0 CO CO• co ti ch 0 CO Cr) O CO At 0 0) LO Cr) CO 0) 00 co CO CO CO (000) 0000 CO Ns CO CO CO 00 0) N CO 1.0 (0 O 0) 00 N e-- 0) N- 0) 0) NI- co co co O N 0) co co CO (0N- 0) 00000000 AlW CD co cp CO `Cr L � 0)) 00)) � 00) � N00)) V • CO Q Cs1 N- 00 N- N N �) 0 0) c' ca 4.4 Cr) Cr) 00) 00)) 00) Cr) Cr) C 0 7 ` Q COCOCOC°CO-r J J J O J Z Mc.) (O RI (/l V NCO _ U - � N CO N � M (V I• CIS Cr) uS N O . 00 C000OO)) coNMN. CCON.O CD 0 N 00 N 0) W CC Q cO — cw tioCLCLreCeCLu_ z ZWWWWW � m U• ZJJJJfo1— O 4E)o ao � U' oF' E E < -0 cn ECOo cn am in c a � = 0 COa co) cy a) •_ O O • C .0 "O a co O U a U O ° O o c O U E >,w o m E t a W c t • O E W O W — O >, CO O O Q a c V) E a o 2a * o) � a U c O a (1) W U � � W C CL co L � WQoy a 0 O J M � O W .3 � W co a_ 4) W � L a) � U) Ec m m U � � � rnm .- u) 00 ed c c c rm.,- ¢O li E O � r O N c0 _ W Op C �_ C co > (fl a a) > a p u) o 2 O> 0 0 O a_ ° ° U) w a) O @ vi LLJ W (a E al C° .g D w Q 3 0 co N co aa) Ct O) aco mi o a 3 0 o f w co 0 c c M f` 0 "� .� �° m U) N F`_ co C p 2 m o c E r p - C �- ui C a) p � � 0_ a) (v� C � oc a�i � � � aCi0 CO 'e o ti ° c N o E73 ca i -0 a) ) (Ni /�£ z .c/ R / = c = �o _ > E cn m E u) e e 2 2 / C ° 0_ 2 � 2e 02 J £ Ofs2 / \% R / k § f a. / / $ 2 § f qa \ / � ) 0 > C 2 ' CO al ® _ CO± / : 0 E ® � � a) 6 % f / / c o - / ƒ f d \ E E f \ = $ / * (0 U) (NI o ix / 6 Q c= 2 / Cl) 0 ca- = % � � 2 0 2 $ c # � � O § \_ ° / 2k (13 G k CU \ $ EE / / / ( O 0 / / \ f / 2 \ t co f / O CO D o ® k Cl-7 E c k k » ° c = e 0 02) co f kf c / f J / ii 0 -ƒ § \ E { � � _\ o ka 2/ > : m _c % 9 0 < # E / co t \ > 0_= % � X- > ° _ X- , N $ CC % o o 7 \ f / / / m G « _/ E % b o g % 5 . E \ g a G E / \w c) o / 0 / / f \ 2 / % @ / N- 2 w I t = _ 01 O a g in / $ = 9- f ((ii) a) � _ c o - * O c c c o (735-12 (1) ? U » g t y ° _ • 7 / 2 C 0) m 2E E/ E ® [ / k ƒ 3® E5 ƒ ƒ 22 '6 : (1) 0- 0 o \ / t % ¢ co ° ° i / / 0_\ i i / � k k/ / > # 7 3 / / / / TREE,. 4-1/16"CMM WELLHEAD= 5M FMC SA, NOTES:H2S READINGS AVERAGE 125 ppm ACTUATOR= OilS P-O 6 B M/ORIGINA ON MI.WELL WEELLREQUIRES IS NOTSSSV SHO NWHEN ON ON KB. ELEV= 7790' — DIAGRAM.'6'4-1/2"CHROM E T BG-"W EL L A NGL E> BF ELEV= 55.41' 70°@ 10185'. KOP= _ 4900; Max Angle= 103°@ 10573' -.--. O 2103' —14-112"OTIS SSSV NIP,ID=3.813" Datum MD- 9964' Datum TVD= 8800'SS GAS LIFT MANDRELS 110-3/4"CSG,45.5#,NT-80,ID=9.950"H 2687' ST MD IVO DEV TYPE VLV LATCH PORT DATE 5 2985 2985 0 CAMCO DMY BK 0 09/21/08 4 5514 5481 24 CAMCO CAN BK 0 09/21/08 Til 3 7729 7224 39 CAMIGO °DMY BK 0 09/21/08 2 9267 8389 43 CAMCO 'DMY BK 0 09/21/08 Minimum ID = 2.37" 10909' 1 9636 8654 44 CAMCO °°DMY BK 0 04/18/04 TOP OF 2-7/8" LNR *STA#2&#3=DMY'S HAVE EXTENDED PACKING *'MANDREL COVERED wICEMENT(10120/05 DIMS) v f- 9647' H3.70"DEPLOY SLV,ID=3.00" 1 ► �' I. 9664' H4-1/7'PKR SWS NIP,ID=3.813"(BEHIND PIPE) 11 1 9666' H3-1/2"HES X NIP,ID=2.813" 1 MO +P 9677' H-5/8"X 4-1/2'TW HBBP PKR(BEHIND PIPE) I 3-1/2"LNR,8.81#,L-80 STL, .0087 bpf,ID=2.990" H 9699' :� (. 9699' H3-112"X 3-3/16"X0,ID=2 867" 'A '1 .1 /, -1 9709' H4-1/2"PKR SWS NIP,ID=3 813" 1 1 9731' —{4-1/7'PKR SWN NIP,MILLED TO 3.80" BEHIND TOP OF 5-1/2"LNRH -9739' 14 I1 9739' H7-5113"X 5.112"TMV LNR HGR W/TBS CT LNR 4-1/2"TBG,12.6#,13-CR.0152 bpf,ID=3.958" H 9742' 111 11 WA! ! 1114, 9743' H 4-1/2"WLEG,ID=3.958" 11 1/ &NOTE TAILPIPE HAS BACKED OFF 1♦ �� 11i IS RESTING ON 5-1/2"LNR TOP 7-5/8"CSG,29.7#,NT-95-HS,ID=6.875" H 9966' F 14 ►�1, L WHIPSTOCK(10/13/05) 9974' ELM `. MLLOUT WINDOW(P-060) 9974'-9982' 111404 , 1�11.141.E 14 109-0-97-1-13-3/16"X 2-7/8"XO, ID=2.441" RI 11.1.N PERFORATION SUMMARY 3-3/16"LNR,6.2#,L-80 TCII, 10909' 11450' —2-7/8"CIPB REF LOG.MIND/EWR/SGRCJSROP ON 10/25/05 .0076 bpf,ID=2.80" ` (09/21/10) ANGLE AT TOP PERF 80°@ 10925' ` Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE PBTD 11561' iiilk, 2' 6 10925- 11050 0 1027/05 -_ - Vii. - 2" 6 11490- 11530 C 1027/05 3.70"BKR RETRIEVALBE BP w/SUPPORT PIPE TO TD H- 11596' ---7," 2-7/8"LNR,6.16#,L-80 STL, .0058 bpf,ID=2.441" 11597' _ n—{ 11600' - DATE REV BY CM/MEWS DATE REV BY COMMBVTS PRUDHOE BAY UNIT 05/23/91 SJA ORIGINAL COMPLETION 10/17/08 MBANPJC GLV CIO(09/21/08) WELL: P-06B 12/25/97 PARKER CT D SIDETRACK(P-06A) 0922/10 SPB/PJC SETCIBP(09/21/10) PERMTNo "2051380 10129105 NORDIC1 CTD SI DET RAC K(P-06B) 02/10/11 MB/JMD ADDED SSSV SAFETY NOTE API No: 50-029-22166-02 11/03/05 DAV/TLH GLV GO 01/18/12 TMMJMD ADDED I-2S SAFETY NOTE SEC 31,T11N,R13E,2506'FSL&1963'FWL 12/05/05 DAV/TLH DRLG DRAFT CORRECTIONS 04/22/12 RCT/PJC SET PX PLUG(4/18/12) 0827/06 JCMPAG GLV GO 06/05/12 RKT/JMD PULLED PX PLUG(06/01/12) BP Exploration(Alaska) • p � T - boa • f Sl3s0 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] /saw th (1/, Sent: Thursday, April 19, 2012 7:50 AM 1 lz- To: AK, OPS GC1 OSM; AK, OPS GC1 Wellpad Lead; AK, OPS Well Pad YP; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OPS Prod Controllers; Brown, Don L.; Daniel, Ryan; Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: Olson, Andrew Subject: NOT OPERABLE: Injector P -06B (PTD #2051380) Secured with plug for further diagnostics Attachments: P -06B TIO 04- 19- 2012.doc; MIT PBU P -06B 04- 09- 12.xls All, Injector P -06B (PTD #2051380) continued to exhibit slow IA repressurization when the IA was bled after the high IAP event on 03/27/2012 as seen in the attached TIO. An MIT -IA passed on 04/09/2012 proving competent barriers in the welibore. A PPPOT -T was also performed and failed. At this time, the well has been secured with a TTP so further wellhead diagnostics can be performed to evaluate whether IA repressurization is occuring through the wellhead. The well is reclassified as Not Operable. The plan forward: 1. Wellhead: Perform Leak Path Evaluation on tubing hanger to verify integrity of wellhead seals 2. Well Integrity Coordinator: Evaluate for Seal -Tite treatment An updated TIO plot and MIT form are attached for reference: «P -06B TIO 04- 19- 2012.doc» «MIT PBU P -06B 04- 09- 12.xls» The well will remain on the Monthly Injection Report while diagnostics are progressed. Thank you, Mehreen Vazrw ` .'J e ('Ilr,'rndue: tii't'ulti "t)t)y') VANE AP $1 �7t1 Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Wednesday, March 28, 2012 7:42 AM To: AK, OPS GC1 OSM; AK, OPS GC1 Wellpad Lead; AK, OPS Well Pad YP; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OPS Prod Controllers; Brown, Don L.; Daniel, Ryan; 'Regg, James B (DOA)'; Schwartz, Guy L (DOA)' Cc: Walker, Greg (D &C); Olson, Andrew; Clingingsmith, Mike J Subject: UNDER EVALUATION: Injector P -06B (PTD #2051380) IA Pressure Increase Over MOASP All, 1 • WAG injector P -06B (PTD #2051380) has exhibited an IA pressure increase of 760 psi over a period of one day. The WHPs on 03/27/2012 were 2470/2100/180 psi. This increase also correlates to an injection temperature increase of over 20 degrees. The well is reclassified as Under Evaluation and may remain on injection while it is evaluated to confirm integrity. The plan forward: 1. Downhole Diagnostics: Bleed IAP to 500 psi. 2. Well Integrity Coordinator: Monitor TIO for 5 -7 days for IAP stabilization. 3. Wellhead: PPPPOT -T 4. Well Integrity Coordinator: Evaluate for MIT -IA A wellbore schematic and TIO plot are attached for reference: « File: P- 06B.pdf » « File: P -06B TIO 03- 28- 12.doc » Please call if you have any questions. Thank you, Mehreen Vazir (.'therm,/c' kluiph -) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com 2 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reggaalaska.aov: doa .aoacc.prudhoe.bavealaska.aov; phoebe.brooksOalaska.00v; tom.maunden.Valaska.aov OPERATOR: BP Exploration (Alaska), Inc. � 161(z, FIELD 1 UNIT I PAD: Prudhoe Bay / PBU / P Pad l DATE: 04/09/12 OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P -06B Type Inj. G TVD . 8,683' Tubing 2000 2000 2000 2000 " Interval 0 P.T.D. 2051380 Type test P Test psi '2170.75 Casing 1000 3000' 2980 2970 P/F P Notes: MIT -IA to evaluate TxIA communication OA _Pumped 4.4 bbls of methanol to reach test pressure Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Vanance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU P - 06B 04 - 09 - 12 ■Ii. PBU P-06B PTD #2051380 4/19/2012 TIO Pressures Plot Wet P-06 4000 - I • 3,000 - • • • • • 4( . - \-. •--.- / 1"--.-•-•-•-•-•-•\ 1 1 -IF- Tbg -IIF- IA 2000 00A On ' n • 1 \ L. 1 .000 ... ' \ • - . ■ ,.. ..._, ...6-111-1,-.•-■-•,, . . . . . . . . 01/21/12 01/28/12 02/04/12 02/11/12 02/18/12 02/25/12 03/03/12 03/10/12 03/17/12 03/24/12 03/31/12 04/07/12 04/14/12 Pr 2J2(3 t Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator@bp.com] 2°” 3/26/t Sent: Wednesday, March 28, 2012 7:42 AM To: AK, OPS GC1 OSM; AK, OPS GC1 Wellpad Lead; AK, OPS Well Pad YP; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OPS Prod Controllers; Brown, Don L.; Daniel, Ryan; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: Walker, Greg (D &C); Olson, Andrew; Clingingsmith, Mike J Subject: UNDER EVALUATION: Injector P -06B (PTD #2051380) IA Pressure Increase Over MOASP Attachments: P- 06B.pdf; P -06B TIO 03- 28- 12.doc All, WAG injector P -06B (PTD #2051380) has exhibited an IA •ressure increase of 760 •si over a seriod of one day. The WHPs on 03/27/2012 were 2470/2100/180 psi. This increase also correlates to an injection temperature increase of over 20.degrges. The well is reclassi ifedas Under Evaluation and may remain on injection while it is evaluated to confirm integrity. 1 6 tARa-etce _ pesswe_ C 14)sh -5 p Jrnta "Eskia The plan forward: 1. Downhole Diagnostics: Bleed IAP to 500 psi. — 2. Well Integrity Coordinator: Monitor TIO for 5 -7 days for IAP stabilization. 3. Wellhead: PPPPOT -T 4. Well Integrity Coordinator: Evaluate for MIT -IA - " 5cf) - scP _ zwo A wellbore schematic and TIO plot are attached for reference: M tr t70f «P- 06B.pdf» «P -06B TIO 03- 28- 12.doc» .- % - 2,5, 7 ` , Please call if you have any questions. Thank you, ` mAR 2 S 2.612 Mehreen Vazir (4 I et rirrtc': Ger <a/cl .Herr /thy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 1 TREE = 4-1/16" CMV • SAFETVIDES: H2S READINGS AVERAGE 125 ppm WELLH = 5M FMC ACTUATOR = WHEN ON MI. WELL REQUIRES A SSSV WHEN ON OTIS P v s B � M!. ORIGINAL WELL (P•06) IS NOT SHOWN ON KB. ELEV = 77.90' DIAGRAM. """'4- 112" CHROM ETBG""WELL ANGLE> BF. ELEV = 55.41' 70° Q 10185'. KOP = 4900' Max Angle = 103° G 10573' ® I 2103' - 4-1/r OTIS SSSV NIP, ID = 3,813" Datum MD = 9964' Datum ND= 8800' SS GAS LIFT MANDRELS 10.3/4" CSG, 45. #, NT - 80, ID = 9.950" H 2687' ST MD ND DEV TYPE VLV LATCH PORT MATE 5 2985 2985 0 CAMCO DMY BK 0 09/21/08 4 5514 5481 25 CAMCO DMY BK 0 09f21/08 3 7729 7224 39 CAMCO 'DMY BK 0 0921/08 Minimum ID = 2.37" 1 ©909' 2 9267 8389 43 CAMCO 'DMY BK 0 0921/08 1 1 9636 8654 44 CAMCO "DMY BK 0 11/03/05 TOP OF 2 -7/8" LNR -STA #2 & #3 = DM Y'S HAVE EXTENDED PACKING "MANDREL COVERED wICEMENT (10120 /05 DIMS) '' 9647' I {3.70" DEPLOY SLV, ID = 3.00" j 1 FA 1� I. [ 9664' - 14 -1/2 PKR SWS NIP, ID = 3.813" (BEHIND PIPE) I ,t , 9666 I- 3 NIP I0 �.. , ' 4 oreil 9677' - 17 -5/8" X 4.1/7' TIN HBBP PKR (BEHIND PIPE) I A AM 13-1/2" LNR, 8.81 #, L-80 STL, 0087 bpi, ID = 2 990 I- 9699' P M 9699' 1— 3 -1 /2" X 3 -3/16" XO, ID = 2.867" 1 111 I 9709' -4-1/2" PKR SWS NIP, ID = 3.813" 9731' - •'I4 - /7' PKR SWN NIP, MILLED TO 3.80" I BEHIND [TOP OF 5.112" LNR, 17 #, 13-CR H -9739' '` ' v ' 9739' I- X 5-1/2" TM/ LNR HGR W /TBS I CT LNR 4 -1/7' TBG, 12,6 #, 13 -CR, .0152 bpf, ID = 3.958" 97 42' . 14 1 .1 ♦4— 9743 - 4 - 1 /2 " WLEG,ID= 3 .958" • - - # k NOTE TAILPIPE HAS BACKED OFF & {p ._ 5t 70 S ; r 1 r. IS RESTING ON 5 -1/2" LNR TOP 1 7 -5/8" CSG, 29.711, NT- 95 -HS, ID = 6.875" H 9966' I I • ��% 4� 1WHIPSTOCK (10/13/05) I ELM I ,' ,. .. -;�• MILLOUT WNDOW (P - 066) 9974' - 9982' TOP OF 2 -7/8" LNR, ID = 2.37" 9998' , 101/...'x . . v.... CIBP (10/09!05 H 100 25' 10908 ' h 3- 3116" X 2 -718" XO, ID - 2.441" II 1 12 -718" LNR, 6.5#, L80, .00579 bpf, ID = 2.37" 1-1 12130 O W t 3- 3/16" LNR, 6.2 #, L -80 TCII, = 10909' ` 11450' - 2 -7/8" CIPB PERFORATION SUMMARY -- (09/21/10) REF LOG: MNR]rEWRISGRC/SROP ON 1025/05 .0076 bpf, ID = 2.80" // ANGLE AT TOP PERF: 80° @ 10925' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE [PBTD 1-1 11561' ``i, 2" 6 10925 - 11050 O 10/27/05 Nkd j _ 2" 6 11490 - 11530 C 10/27/05 13.70" BKR RETRIEVALBE BP w /SUPPORT PIPE TO TO H 11596 I 2 -7/8" LNR, 6.16 #, L -80 STL, 0058 bpf, ID= 2.441 "1 11597' TD --I 11800' DATE REV BY COMMENTS ' DATE REV BY COMMENTS PRUDHOE BAY UNIT 05123/91 SJA ORIGINAL COMPLETION 10/17/08 MBNVPJC GLV CJO (09/21/08) WELL: P-066 12125/97 PARKER CT D SIDETRACK (P-06A) 09/22/10 SPB /PJC SET CIBP (0921 /10) PERMIT No: `2051380 10129/05 NORL C1 CT D SIDETRACK (P-06B) 02/10/11 MB/JMD ADDED SSSV SAFETY NOTE API No: 50-029-22166-02 11/03/05 DAV/TLH GLV CJO 01/18/12 TMWJMD ADDED I-t2S SAFETY NOTE SEC 31, T11 N, R13E, 2506' FSL & 1963' FWL 12/05/05 DAV/TLH DRLG DRAFT CORRECTIONS 0827/06 JCMPAG GLV C/O BP Exploration (Alaska) • • PBU P -06B PTD # 2051380 3/28/2012 TIO Pressures Plot Wet P -06 6.000 3900 - Tbk -4.— a 2000 - — 0A 00A — - 000A Oe 1.000 - 12/31/11 01/07/12 0194/12 01/21/12 01/28/2 02104712 02111/12 02/6/12 02{25112 03/0312 03/10/12 03/17/12 03/2412 Injection Plot Welk P-06 1200 -15,003 3,100 3.000 - 14003 2.600 2600 • L 1 1 I -13Am 270D G 2600 - 12.000 2,500 2400 - 11.000 2300 2200 2100 -10900 2 - 9.000 1,900 — WHro 1.800 yy 91,700 -8.000 — POI 1900 X — 171 1,500 - 7000 Q — GI 1,100 a —oe. ".,300 - 6,060 On 200 ��q q� t 100 5 N`/ .rtt. 5900 1.000 900 R -1.000 800 700 - 3900 600 ' 400 300 - 2,000 200 000 200 799 12/31/1 0191792 019412 01/21/12 01/28/12 02/04/12 0291/12 021112 02/2.12 033913/12 0390/2 21/17/12 03/24/12 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 't.'0:40) ?Li August 22, 2011 RECEIVED Mr. Tom Maunder AUG 31 ZO1 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, & Gets Cow Commission Anchorage, Alaska 99501 Ancbersgo Subject: Corrosion Inhibitor Treatments of GPB P -Pad �._ ) Dear Mr. Maunder, -- o10 8 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB P- 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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) P -Pad Date: 07/21/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal P - 1920920 500292228700 0.30 NA 0.30 NA 0.85 4/24/2010 P -02A 2000840 500292237601 0.30 NA 0.30 NA 4.25 4/25/2010 P -03A 1972280 500292217601 12.70 5.0 0.30 7/12/2010 2.55 8/5/2010 P -04 1910760 500292218000 1.80 NA 1.80 NA 15.30 4/25/2010 P -05A 2000510 500292254501 0.80 NA 0.80 NA 5.95 4/25/2010 P -06B 2051380 500292216602 11.30 3.0 1.00 7/12/2010 9.35 8/5/2010 P -07A 2011960 500292253501 0.50 NA 0.50 NA 1.70 4/24/2010 P -08A 2000850 500292237701 P -09 0.10 NA 0.10 NA 0.85 4/24/2010 1930580 500292236200 1910520 500292215800 0.10 NA 0.10 NA 0.85 4/24/2010 P -10 3.00 NA 3.00 NA 28.05 4/24/2010 P -11 1910290 500292214300 3.00 NA 3.00 NA 23.80 4/23/2010 P -12B 2001330 500292213602 0.30 NA 0.30 NA 0.85 4/23/2010 P -13 1901110 500292208000 0.30 NA 0.30 NA 1.70 4/23/2010 P -14 1910070 500292212900 7.50 NA 7.50 NA 56.10 7/21/2011 P -16 1901630 500292211300 4.30 NA 4.30 NA 37.40 4/22/2010 P -17 1901550 500292210500 8.00 NA 8.00 NA 89.30 4/28/2010 P -19 1901360 500292209400 0.80 NA 0.80 NA 5.10 4/21/2010 P -20B 2001590 500292208902 0.20 NA 0.20 NA 0.85 4/21/2010 P -21B 1970640 500292214802 0.40 NA 0.40 NA 4.30 4/21/2010 P -22 1931210 500292239600 0.30 NA 0.30 NA 1.70 4/23/2010 P -23 1931120 500292239300 0.30 NA 0.30 NA 0.85 4/24/2010 P -24 1970540 500292275500 1.80 NA 1.80 NA 8.50 4/24/2010 P -25 1970260 500292274200 64.00 24.0 2.60 7/17/2011 23.80 7/20/2011 P -26 1962000 500292272700 2.60 NA 2.60 NA 22.10 4/25/2010 P -27 2040500 500292320300 1.00 NA 1.00 NA 6.80 4/25/2010 P -28 2100480 500292342500 1.20 NA 1.20 NA 10.20 8/7/2010 1 I • • SEAN PARNELL, GOVERNOR Don Brown Petroleum Engineer P.OEBox 196612Alaska), Inc. ~b~0~~~ `1F~~~~ ~C}~lu'= Anchorage, AK 99519-6612 ~ '~ a~,,.,_ Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU P-06B Sundry Number: 310-243 Dear Mr. Brown: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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 reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, :~ Daniel T. Seamount, Jr. i~` \ Chair DATED this ~ day of August, 2010. Encl. STATE OF ALASKA C/~ ' ALASK~L AND GAS CONSERVATION COMMISSION ~~ APPLICATION FOR SUNDRY APPROVALS ~,~~~ 20 AAC 25.280 tNl. ~'1°~~~ 1. Type of Request: Abandoi^ Plug for Redrill ^ Perforate New Pool^ Repair Well^ Change Approved Program^ Suspen~ Plug Perforations ^~ - Perforate^ Pull Tubing^ Time Extension^ Operation Shutdowr^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ ^ Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 205-1380 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service Q _ 6. API Number: Anchorage, AK 99519-6612 50-029-22166-02-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Ye^ No ^ PBU P-066 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028288 - PRUDHOE BAY Field / PRU DHOE BAY Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11800 - 9033.06 " 11561 _ 9024 _ NONE NONE Casing Length Size MD ND Burst Collapse Structural Conductor 120 20" 91.5# h-40 63 183 63 183 1490 470 Surface 2625 10-3/4" 45.5# N-80 62 2687 62 2687 5210 2480 Production 9905 7-5/8" 29.7# NT95HS 61 9966 61 8893 8180 5120 Liner 237 5-1/2" 17# NT13CR80 9739 9976 8728 8900 7740 6280 Liner 1210 -3/16" 8.81 L-80 9699 10909 8699 8997 8520 7660 Liner 891 7/8" 6.16# L-80 10909 11800 8997 9033 13450 13890 Liner 52 3-1/2" 8.81# L-80 9647 9699 8662 8699 10160 10530 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): O 10925 - 11050 8999.37 - 9024.33 4-1/2" 12.6# 13CR880 58 9743 O 11490 - 11530 9028.4 - 9025.45 Packers and SSSV Tvoe: 7-5/8" TIW HBBP PKR Packers and SSSV MD and ND tft): 9677 8683 4-1/2" OTIS SSSV NIPPLE 2103 2103 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/11/2010 Oil ^ Gas ^ WDSPL ^ Suspended ^ 16. Verbal Approval: Date: WINJ ^~ -S GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Don Brown Printed Name Don Brown Title P E Sig ture `~ Phone Date O~ 564-4323 8/5/2010 Prepared b Gary Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ~ ~ ~ r~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. r^~ ~ f+~~i./ ~~~...r+ (' ^i ~~ to G/ L/ uent Form Re uired: ~ ~ - / v ` Subse r+ q q s ts )t~ :~ ~ ~~r H '~~" a + ! ~Y~t~~~t~±r~?ge APPROVED BY A roved b : COMMISSIONER THE COMMISSION ~ ! Date: pp y ~ IOti ~-~o IRIS AUG 12101p ,~~~ ~~y~6 Form 10-403 Revised 1/2010 ~ O R Submit in Duplicate IGIN • • ~~ To: Jerry Bixby /Clark Olsen Date: August 4, 2010 GPB Well Ops Team Leaders From: Don Brown, P-Pad Engineer AFE: APBPPDWL06-R Est. Cost: $120,000.00 Reviewed by Jack Lau Subject: P-06B CIBP Set w/ WeIITec Tractor IOR: 50 1. S Pull MCX, Drift as deep as ossible, Brush & Flush if needed 2. F SBG Treatment 3. E D&T, Set CIBP w/ WeIITec Tractor > Current Status: Injecting PW Last Injection: July 2010 PWI rates: 4000 BWPD, 1100 PSI Max Deviation: 103° @ 10573' MD Perforation Deviation: 80° @ 10925' (top perf) Min. ID: 2.377" Top of 2-7/8" Liner @ 10909' Last Tag: 03/30/09 - IPROF with tractor at 11529' ELM Last Downhole Ops: 04/07/09 -set 4-1/2" MCX Last SBHP: 07/21/06: 3307 psi, 214°F Latest H2S value: Not tested (P-06A 15 ppm on 03/04/02). Ref Log: Sperry MWD LOG ---Primary Depth Control Log (10/25/2005) Job Objective: The objective is to set a CIBP between the heel and toe perfs to improve pattern Well History: P-06B was CT Sidetrack drilled in 10/29/2005. It was initially a production well before being converted to a WAG =*: injection well (08/27/2006). The well then failed aMIT-IA to 2500 psi (09/05/2006) and the LLR was "too small to track" and the well was then placed on PWI only AA for TxIA communication. Prior to any injection, the well needed =*' a methanol CTU jet job followed by a pert wash and break down with a TD tag at 11,539' CTMD. In an attempt to :r get this injector on MI, DGLV's #2, #3, #4 & #5 were pulled and new DLGV's were set with DGLV #3 @ 7729' receiving extended packing as it had previously as a producer. GLM #1 is covered by cement (10/20/2005 DIMS) = and the well has passed aMIT-IA. An IPROF was run in March of 2009 which indicated that 87% of the injection was going into the toe perfs which are located next to a fault. Producers in this pattern have not seen any benefit from the last MI bulb leaving questions if all the injection has been going into the fault. 3 Ann Com History: > 01/17/09: MITIA Passed to 2500 psi > 01/21/09: AOGCC MITIA Passed to 3000 psi > 04/07/09: Re-Set MCX > 11/05/09: AA cancelled for TxIA comm. For questions or comments please call Don Brown 564-4323 (w), 745-8386 (h), 351-7108 (c). Cc: Wellfiles • Risk Discussion: • There was a tight spot noted on 08/26/06 WSR between 1078' -1209' MD. • Note that well has a history of paraffins, schmoo, and hydrates (08/26/06 and 10/12/06 WSR). • Well has 4-1/2" Chrome tubing Slickline: 1. RU SL and pull 4-1/2" MCX (ser# NM-16, .625"bean) @ 2,079' SLM, 2,103' MD. 2. Drift as deep as possible (for tractor 2-1/8"). Use PE discretion on drift assembly. Well may have some schmoo but has recently come off of MI. If possible, obtain a sample of schmoo if any is encountered. Note: Well surpasses 70° at 10190' MD -directional survey attached to bottom of program. Fullbore: 3. Pump 30 bbls of SBG (2 x volume of the liner) to bottom pert (11530' ELM) and shutdown for at least three hours to soak. 4. Have PCC place back on injection. E-Line w/tractor: Note: • Use a third party crane (contact central dispatch at x5049) 1. RU E-line. Drift to deviation w/ WeIITec Tractor without logging tools as deep as possible using weight bars to simulate tools. Note: small liner size (2.441" ID) with a 2-1/8" tractor tool. Be sure to use tractor with small wheels that fully retract into tractor body. 2. MU 2-1/8" WeIITec Tractor and RIH with CIPB to 11,100' and set plug. (Plug just has to be set between the two sets of perfs, bottom pert on heel set is 11,050' MD, top pert on toe set is 11,490' MD; see log attached). '"-~ 3. POOH, RDMO, contact PCC to place back on injection 2 U TRH = 4-1 /16" CNV WB_LHEAD= SMFMC ACTUATOR O11S KB. H EV = 77 90' BF ELEV = 55A1' KOP _. 4900 Max Angle = 103 @ 10573' Datum MD= 9964' DatumTVD = 8600' SS 10.314" CSG, 45.5#, NT-80, D = 9.950" ~-{ 2687' Minimum ID =2.37" @ 10909' TOP OF 2-718" LNR 3-1/Z" LNR 8.81#, L-80 3TL, .0087 bDf, D = 2.990° iTOPOF5-1/2' LNR 17#,13-CR h 9739 4-112" TBG, 12.6#,13C R .0152 bpf , D = 3.958' 9742' 7-5/8° CSG, 29.7#, NT-95•HS, D = 6.875 H 9966' W FH~STOCK (10113105) 9974' d TOP OF 2-7/8" LNR, D = 2.37° 9998' CBP (1 or09/Q5) 10025 2-718" LNF; 6.5#, L80, .00579 bpf, D = 2.37° i PERFORATDN SU~AMARY REF LOG: biWD+EWWSGRGSI~P ON 10/25/05 ANGLE ATTOP PERF: 80 ~ 10925 Note: Refer to Roduction ~ fa histor~a! pert data SQE SFF MBNAL Opn/Sgz DATE 2° 6 10925 - 11050 O 1027105 2" 6 11490 - 11530 O 10127/05 • SAFEfY NOTES: OPoGINAL WaL (P-O6) IS NOT SHOWN P ~O ~ B ~CHRO~ME412" TBG'*' ® 2103' 41rz• oils sssv NP, D = 3.813" GAS LFT MANDRELS i.oo7s bpr, D = z.ao° ~PBro H 11561' F--" 3.70°BKRREIREVALBEBPw1SL~PORTPPETOIU 11$96' 2-718" LNR 6.16#, L-80 STL, .0056 bpf, D = 2.441" 1159T C ~ BP ~ O r ~ /l~ / ao DATE REV BY COMM9dTS DATE REV BY COMMFNtS 0523NJ1 SJA ORIGINAL COMPLETION 90/17!06 MBMPJC GLV GO(09/21/08) 1225197 .PARKER CTDSIDEiRACK(P-O6A) 1029105 NORDIC1 CTDSIDETRACK(P-066) 11103/05 DAVRIH GLV GO 12/05105 DAVlfLH DRLG DRAFT CORRECTIONS 0827106 JCANPAG GLV GO PRtAFK)E BAY ld~i WB-L: P•O66 PH~MIT No: 2051380 API No: ~-029-22166-Q2 SEC 31, T11N, R13E, 2506' FSL 8 1963' FWL BP Ecploration (Alaska) ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2985 2965 0 CAMCO DMY BK 0 09!21/08 4 5514 5481 25 CAMCO OMY BK 0 09/21/08 3 7729 7224 39 CAMCO 'DMY BK 0 09!21!08 2 9267 8369 43 G~MC.O "DMY BK Q 0921/06 1 9636 8654 44 CAMCO "DMY BK 0 113/05 " .71 A iFL 685 = UM !'A HP1V t t7l 1 tl'aJt1J YALNNb "`MANDRa COVHOB)w1CEMENi (1020105 DIMS) 9647' 3.70" DEPLOY SLV , D = 3.00" 9664' 41/2" PKR SWS NP, D = 3.813° (B@OND PIPE) 9666' 3-112" HES X NP, D = 2.813° 9677' - 7-5/8" X 4-12" TNV hBBP PKR (BEHIND PIPS 9699' 31/2" X3.3116° XO, D = 2.867" 9709' 4-112 PKR SWS NP, D = 3.813" (BEHIND PIPE) 9731' 41/T PKR SW N NN? Pod.LED TO 3.80' (BEHIND PIPE) 9739' T-Sl8" X 5-12" TIdV LNR HGR W/TBS (B@0ND PIPE) 9743' 4112° WLEG, D= 3.958" (Bt3~iNDPIPE) NOTE TAILPIPE HAS BACK® OFF 8 IS RESTING Ofi 5-12"LNR TOP M ILLOUT WINDOW (P-06B) 9974' - 9982' 10909' 33!16° X 2-718' XO, D = 2.441' 3 • BP~Exploration Short Well Name: P-066 W Name. DRILLPAO P NO 068 Operator. BPx L RVN_DA7E. 30-Mar-2009 DnlleO Depth 11800' putl Date 2005-tOQ200.00:00 XCoortlinate. 631246 easurement Ref KB Y Coortlmate 590233 e( Elevahon 92.1 Depth Ranqe 9900'-'20 ayout Name. Ijl_horizontal Vertical Scale 1 2100 RGPM DEPTH TVD Perfs WORD ICL Fluids ~ _ _ -s- TM4 TWS .aMul~ - -:+TT-- _. r.- rear 55 GRMM Borehole Profile EWR MIND 1 _ TSHA - 4450 ~oooo i~g$ )g7 §~ T B seas _._-_ 10050 -8600 TSHC -ee']o _ 8880 --~~ -._ - 10100 .8870 -8700 -di . - 10130 -8910 ~=.,, -8720 ._ 10200 -8730 _~ 10230 8740 10300 -8700 -e7eo TSAD - 10350 10600 ~~. 10150 ,®000 -~~- 10500 ' _ 10330 loeoo -8930 -8940 _ 10030 10]00 8730 -8720 10]30 -8710 _ _ 10800 TSAD ~~-V 3 10830 __. _ --~ ... _.-_.. - 1 0700 ~„~___.-.. ~ 10730 '8710 -~ - -8720 ~ rOF~-p Irx7. = -oAS08 ae~r Lsp: '~}n -~ '." 11000 '_ a. ~mmae ~- t 11030 -8030 °' y. 11100 8710 -~ - - „~- 11150 11200 _8930 j _ ~~ s®-~~. 11250 11300 -8730 TSAD '~ ++350 ~. - -' 2 11400 -' 11430 -8740 .~~+~- ~ 11300 ~ itJ p,p ir53p_ ^.oc4~W PertI 3a {sue gun m. ' 11330 y ~ 11000 y p ~-~..~ `~ws.- _ ~~ +'- t t 630 -8730 ~ ' 11 ]00 -8730 ---- ~-~ __ __ 11]50 11800 '8710 I~ I • P-06B Well Deviation Survey 10/25/2005 Well Bore API/UWI Survey Type Company Name Survey Date MDT (MD) MDB (MD) P-066 5E+11 MWD Halliburton 10/25/2005 0 11,800 MD (ft) TVD (ft) SS (ft) Inclination Azimuth Dog Le 0 0 -92.1 0 0 0 487 487.4 395.3 0.22 322.51 0.2 504 504.15 412.05 0.25 323.95 0.2 989 989.19 897.09 0.17 305.55 0.3 1,006 1,005.89 913.79 0.18 288.97 0.3 1,484 1,484.44 1, 392.34 0.27 223.39 0.4 1,501 1,500.84 1,408.74 0.22 203.9 0.6 1,993 1,993.39 1,901.29 0.17 128.97 0.2 2,010 2,009.69 1,917.59 0.17 130.38 0 2,497 2,497.18 2,405.08 0.08 183.85 0.4 2,514 2,513.48 2,421.38 0.13 187.36 0.3 2,986 .2,986.08 2,893.98 0.2 179.91 0.2 3,002 3,002.03 2,909.93 0.2 208.11 0.6 3,589 3,589.02 3,496.92 0.37 227.82 0.3 3,605 3,604.66 3,512.56 0.43 239.19 0.6 4,091 4,090.64 3,998.54 0.85 217.69 0.1 4,106 4,106.34 4, 014.24 0.88 215.12 0.3 4,494 4,493.59 4,401.49 0.48 201.11 0.1 4,509 4,509.04 4,416.94 0.45 197.72 0.3 4,988 4,985.05 4,892.95 12.22 345.68 3.8 5,003 4,999.94 4,907.84 12.73 346.28 3.5 5,479 5,449.58 5,357.48 23.75 352.73 0.8 5,501 5,469.42 5,377.32 24.03 352.56 1.3 5,983 5,891.87 5,799.77 33.58 350.82 2.4 6,011 5,915.19 5,823.09 34.23 350.9 2.3 6,491 6,288.23 6,196.13 41.25 351.27 0.1 6,519 6,309.04 6,216.94 41.32 351.32 0.3 6,991 6,660.95 6,568.85 42.12 351.3 0.2 7,019 6,681.57 6,589.47 42.1 351.33 0.1 7,486 7,035.92 6,943.82 39.48 352.71 0.3 7,514 7,057.12 6,965.02 39.4 352.71 0.3 7,978 7,419.14 7,327.04 38.98 356.88 0.9 8,005 7,439.95 7,347.85 39.18 357.21 1.1 8,489 7,811.18 7,719.08 39.77 2.83 0.8 8,516 7,831.86 7,739.76 39.75 3.2 0.9 8,993 8,189.64 8,097.54 43.23 7.63 1 9,019 8,208.99 8,116.89 43.25 7.99 0.9 9,483 8,544.60 8,452.50 44.37 13.46 0.6 9,503 8,558.81 8,466.71 44.5 13.6 0.8 9,993 8,912.04 8,819.94 44.41 21.35 8 10,021 8,931.35 8,839.25 47.05 21.2 9.6 10,062 8,958.43 8,866.33 52.07 20.91 12 10,092 8,975.98 8,883.88 56.04 20.55 13.3 ~ s 10,122 8,991.77 8,899.67 60.26 20.2 14.1 10,154 9,006.50 8,914.40 65.37 16.85 18.3 10,185 9,018.18 8,926.08 69.87 13.33 18.1 10,215 9,028.19 8,936.09 71.43 10.84 9.3 10,249 9,038.05 8,945.95 75.07 1.88 27.3 10,281 9,045.31 8,953.21 78.59 357.47 17.4 10,312 9,050.73 8,958.63 80.97 351.13 21.9 10,344 9,054.52 8,962.42 85.37 353.24 15.3 10,375 9,056.09 8,963.99 88.9 356.94 16.3 10,409 9,055.67 8,963.57 92.51 2.23 19 10,443 9,053.60 8,961.50 94.36 8.22 18.1 10,482 9,050.52 8,958.42 94.79 16.65 21.8 10,513 9,046.46 8,954.36 100.18 14.21 19 10,540 9,041.22 8,949.12 102.47 15.44 9.7 10,573 9,033.79 8,941.69 103.08 7.51 23.1 10,605 9,027.07 8,934.97 101.59 3.64 12.9 10,632 9,021.71 8,929.61 100.62 358.35 19 10,664 9,015.80 8,923.70 100.88 349.89 26.3 10,703 9,008.73 8,916.63 100.09 345.14 12.2 10,732 9,004.06 8,911.96 98.5 341.08 14.9 10,761 8,999.42 8,907.32 99.82 334.56 22.6 10,792 8,995.33 8,903.23 95.25 337.33 17.1 10,824 8,993.80 8,901.70 90.22 338.09 15.9 10,856 8,993.87 8,901.77 89.52 341.08 9.8 10,887 8,995.06 8,902.96 86.17 345.84 18.5 10,916 8,998.06 8,905.96 82.03 348.13 16.1 10,954 9,005.15 8,913.05 76.12 347.78 15.8 10,989 9,013.11 8,921.01 77.8 341.96 16.8 11,027 9,020.53 8,928.43 79.74 335.97 16.3 11,058 9,025.50 8,933.40 81.67 331.92 14.4 11,085 9,028.90 8,936.80 84.14 329.98 11.4 11,122 9,032.53 8,940.43 84.41 324.34 15.4 11,152 9,035.42 8,943.32 84.49 320.82 11.8 11,185 9,039.29 8,947.19 82.38 314.65 19.2 11,222 9,043.06 8,950.96 85.73 312.54 10.9 11,251 9,044.22 8,952.12 89.69 310.25 15.6 11,282 9,043.57 8,951.47 92.69 307.07 13.9 11,315 9,041.85 8,949.75 93.3 304.25 8.8 11,346 9,039.68 8,947.58 94.89 305.84 7.4 11,380 9,036.76 8,944.66 94.98 312.71 20.2 11,415 9,033.80 8,941.70 94.63 319.58 19.4 11,450 9,031.23 8,939.13 93.74 325.4 16.7 11,487 9,028.61 8,936.51 94.36 328.92 9.6 11,520 9,026.12 8,934.02 94.36 335.09 18.8 11,554 9,024.59 8,932.49 90.75 334.21 10.8 11,584 9,024.08 8,931.98 91.19 340.55 21.3 11,614 9,023.43 8,931.33 91.28 340.03 1.8 11,646 9,021.98 8,929.88 93.92 334.03 20.6 11,678 9,021.01 8,928.91 89.6 330.16 18.4 11,710 9,022.35 8,930.25 85.73 326.99 15.3 11, 743 9, 025.22 8, 933.12 84.14 324.87 8.1 11,772 9,028.84 8,936.74 81.41 319.94 19.5 11,800 9,033.06 8,940.96 81.41 319.94 0 OPREABLE: P-06B (PTD #20380) No Indication of TxIA Communion on MI Page 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~~ ~~~~~, Sent: Monday, April 20, 2009 12:50 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Brown, Don L. Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer; Winslow, Jack L. Subject: OPREABLE: P-066 (PTD #2051380) No Indication of TxIA Communication on MI Attachments: P-06B TIO Plot.doc All, Well P-06B (PTD #2051380) has been on MI injection since 4/08/09 with no indication of TxIA communication. The AOGCC Administrative Approval will remain in place for a few more months to ensure no further integrity issues. Once more TIO data has been obtained, a request for AA cancellation will be sent to the AOGCC. The well has been reclassified as Operable and may remain on WAG injection. A recent TIO plot has been included for reference. «P-066 TIO Plot.doc» Please let us know if there are any questions. Thank you, Anna ~Du6e, 2~.~. Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: (907} 659-5100 x1154 ''< ~~ APR ~,~ ~~ ~0~ From: NSU, ADW Well Integrity Engineer Sent: Saturday, February 28, 2009 7:02 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr Central (GCl/3/FS3); GPB, GCS OTL; GPB, GCl Wellpad Le •GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt En rown, Don L. Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot Subject: UNDER EVALUATION: P-06B (PTD #2051380) Swap to MI and Monitor for TxIA All, P-06B (PTD #2051380) has exhibited TxIA communica ~ fi when on MI injection in the past and is currently under AA 3.015, which restricts the well to produced wateyr section. In an attempt to restore the well's integrity to miscible gas injection, a slickline intervention ins#~Tled new dummy gas lift valves with extended packing in mandrels #2 and #3 (9267' MD and 9636' N(D)`~on 09/21/08. The well subsequently passed an MIT-IA to 4,000 psi on 09/22/08 and an MIT-IA to 3,000 psi on 01/21/09. The well has been reclassified as Under Evaluation and placed on a 28-day clock to evaluate-the success of the repair. Our plan forward for the well is as follows: 4/20/2009 PBU P-06B PTD #2051380 4/20/2009 TIO Pressures 4,000 3.000 2,000 1,000 ~- Tbg -~ IA -~- OA OOA -~- OOOA On • 01124!09 01!31!09 02!07!09 02!14!09 02121!09 02!28!09 03107!09 03!14109 03121!09 03128/09 04!04109 04!11!09 04/18109 • PBU_P-066_TxIA_MI_test_update_2009-0416.txt P-066 (PTD #2051380) Request to swap to MI InjectionFrom: NSU, ADw well Integrity Engineer [NSUADWWe1lIntegrityEngineer@BP.com] sent: Thursday, April 16, 2009 10:32 AM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T. Subject: RE: P-066 (PTD #2051380) Request to swap to MI Injection Hi Jim, Thank you for checking in on P-066 (PTD #2051380). so far the TIO plot is showing no indications of communication. we are planning to review this well with Steve Rossberg next Tuesday and seek cancellation of the AA for IA repressurization. Please let me know if you agree with this planned action. Thank you, Anna Dube, P.E. well Integrity Coordinator GP8 Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 -------------------------------------------------------------------------------- From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] sent: Thursday, April 16, 2009 9:47 AM To: NSU, ADW Well Integrity Engineer Subject: FW: P-066 (PTD #2051380) Request to swap to MI Injection Any results from the temp swap to MI in PBU P-066? Jim Regg AOGCC 333 w.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (DOA) sent: Monday, March 09, 2009 3:21 PM TO: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: P-06B (PTD #2051380) Request to swap to MI jection I have reviewed the well service reports coveri the installation of dummy GLVS and the MITIA performed subsequent to the slickli intervention. BP is authorized to initiate temporary injection of MI into PBU -066. Injection may not exceed 28 days from commencement. Injection must be imm iately discontinued and notice provided to the Commission if there is any Indic ion of pressure communication or leakage. Jim Regg AOGCC 333 w.7th Avenue, Suite 100/ Page 1 00 M ~. ~ o v ~~ ~ ~ a ~ 1 d- J d Q ~ aCoo c f-~ooao ~•t ^ Q T T _~ O O ~A M d Q~ 1, T N ~~ {~ J O T 1 M ~_ ~ti J ~~ N N O ~1 G T N ~~ N ~/ d 1. T N O J1 O r~ 0 0 m 0 T M r O 07 O N O ~i O }- ~- t ~, _~ O O Q O G ~ O O cr M N r- ~J 04/06/09 N0.5162 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 ~- (y Anchorage, AK 99503-2838 `, r~,~~ r~~ ~~ )*,' .~ ~;~i% p Alaska Oil & Gas Cons Comm -- Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 WP_II .Inh iF ~ .... n ........:...:__ ~ti MPS-08 AY3J-00016 -' -"' ~ LDL 03/23/09 1 VVIVI VV 1 04-22A BiJJ-00003 MEM L L 03/24/09 1 1 15-15C BOOR-00004 MEM PROD & INJ PROFILE _ ~ ~-~~ 1 03/15/09 1 1 4-04lf-26 AP3O-00028 _ USIT 03/21/09 1 1 P-06B AY3J-00016 INJECTION PROFILE 03/30/09 1 1 E-05A B1JJ-00003 CH EDIT PDC-GR (JEWELRY LOG) /cj'Q _ 3 02/08/09 1 06-14A BOOR-00004 CH EDIT PDC-GR (JEWELRY LOG) r"~-- 02/21/09 1 F-33A 40018553 OH MWD/LWD EDIT a(o 01/25/09 2 1 F-33A PBi 40018553 _ OH MWD/LWD EDIT _ ~ t '} 01/14/09 2 1 ~~ . --_______.-.__-.____.~..~~_.. ~. .............-..... ...-.....,.n.v, v~..-vvr. cr~a.n ~v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E, Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Str et, Suite 400 Anchorage, AK -2838 ATTN: Beth ,.--`' Received by: P-06B (PTD #2051380) Reque~ swap to MI Injection Regg, James B (DOA) From: Regg, James B (DOA) ) Sent: Monday, March 09, 2009 3:21 PM ~ ~~ ~I ~' ~~~`~~] To: 'NSU, ADW Well Integrity Engineer' Cc: Maunder, Thomas E (DOA) Subject: RE: P-066 (PTD #2051380) Request to swap to MI Injection • _ Page, l of 2 I have reviewed the well service reports covering the installation of dummy GLVs and the MITIA performed subsequent to the slickline interven6on_ BP is authorized to initiate temporary injection of MI into PBU P-06B. Injection may not exceed 28 days from commencement. Injection must be immediately discontinued and notice provided to the Commission if there is any indication of pressure communication or leakage. Jim Regg AOGCC _ '" 1'°f~ ~~~ ~ 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Sunday, February 15, 2009 4:54 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: P-06B (PTD #2051380) Request to swap to MI Injection Hi Jim, 1've included twa pdf files; one for the slickline work and one for the MITIA on 01/21/09. The well service report for the dummy gas lift valves includes the MITIA to 4000 psi on 9!22/08. Our intention is to monitor the well for twa weeks on MI before making a determination. Given the thermal effects due to temperature and rate, we may decide to monitor the well for up to as much as four weeks; however it is unl"skely that this much time will be necessary. Please let me know if you have any additional questions. Thank you, Anna 1~u6e, ~.~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: (907} 659-5100 x1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, February 12, 2009 11:06 AM To: NSU, ADW Well Integrity Engineer Subject: RE: P-06B (PTD #2051380) Request to swap to MI Injection 3/9/2009 P-06B (PTD #2051380) Requ~o swap to MI Injection • Page 2 of 2 Can you send well service rpt for installing dummy gas lift valves? Also, MITs done 9/22/08 and 1/21/09. How long would you inject Mf before making the determination there is (not) communication? Jim Regg ~/ 333 W.7th Avenue, Suite 100 ` ~'~~> ~` ~SS Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Thursday, February 05, 2009 4:22 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW Well Integrity Engineer; Engel, Harry R; NSU, ADW Well Integrity Engineer; Brown, Don L. Subject: P-06B (PTD #2051380) Request to swap to MI Injection Jim and Tom, P-066 (PTD #205138 j as exhibited TxIA communication when on MI injection in the past and is currently under AA 3.015, which restricts th_ a well to produced water iniection. In an attempt to restore the wel's integrity to --~~~ miscible gas injection, a slickline intervention installed new dummy gas lift valves with extended packing in mandrels #2 and #3 (9267' MD and 9636' MD) on 09/21%08. The well subsequently passed an MIT-IA to 4,000 psi on 09/22/08 and an MIT-IA to 3,000 psi on 01/21/09. The latter test was witnessed by Chuck Scheve. Our proposed plan forward for the well is as follows: 1. WOE: Swap well to MI injection. 2. WIC: Reclassify as Under Evaluation and monitor IA repressurization. 3. WIC: Submit AA cancellation if no communication is observed, or swap well back to water if communication still exists. A wellbore schematic has been attached for reference. «P-066. pdf» Please let me know if you need additional information to aid in a decision. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 3/9/2009 WellServiceReport • WELL SERVICE REPORT • Page 1 of 1 WELL JOB SCOPE UNIT P~06B PRESSURE TEST (INTEGRITY) SWCP #08 DATE DAILY WORK DAY SUPV 9/20/2008 IN PROGRESS JONES COST CODE PLUS KEY PERSON NIGHT SUPV PBPPDWL06-I SWCP-FINCH FORE MIN ID DEPTH TTL SIZE 2.37 " 10909 FT 0 " DAILY SUMMARY __.w__..._._ _.____._.~ _.._._....._......_. _~_.__._~__...._.~_...__._.._...__._._...~._____-__.._.._._......__._.._..~.._,~,......___.._. _._..._.~...~.._,.._._......_,.._.~,_,_.._,_.._...__._,.__.__.. ***WELL INJECTING ON ARRIVAL*** ATTEMPT TO RIH W/ 4 1/2 XN C-SUB ***CONTINUED ON WSR 09/21/08*** Init Tbc. IA. OA -> 18:00 DSO NOT ALLOWING WORK ON WELL 13-30...C/O CAMP...CALL REP .___..._._.,.. ___~_._.~.~.__ __~_. _._.___._._.._._.__.___________... ____.._.....__.__..__._..._._.._.....__._~.._...._......~___.w.__._..._____. 20:05 TRAVEL FROM WCP TO WLB FOR TOOLS, PACKAGE FOR P-06 20:06 SPOT EQUIPMENT, INSPECT LOC, PJSM, JSA REVIEW..STANDBY FOR PAD OP(NOT ALLOV UNTIL PAD OP__ON LOC~._PULL WIRE, REPACK STUFFING BOX 21:05 PAD OP LOC TO DISCUSS JOB...SIGN PERMIT 21:2_0 BEGIN R/U .12_5 WIRE 23 TURNS T.S. 5' x 2.625" WB, OJ, LSS ...__.__._______.._.~._._.___._.__......__..__.w.._..__.._.._,. _..____..._~.._,._.. _..._~...~_____..__. _...._.. 21:35 FLOW LINE AND WELL FP W/ 50/50..CYCLE SWAB _~.._.__._ _.,_.__..___....._...._,.. w._. .__.~__ _.__.__ ___.___ ...,,._ ... _._.. ._. 22:15 POP CAP, PT LUB 300# LOW, 3000# HIGH ._._ _______._____.__.._.__._._.__~......_.,.___.._.__.._._..__.__~_~_.u.~....~_.____,.,~..__._._~,__._. 22:50 RIH W/ 4 1/2 GS, 4 1/2 XN C-SUB...FL @ 530'...MANY TIGHT SPOTS FROM 900' SLM TO 1400' REP..POOH 23:09 REP ON LOC FOR AWGRS 23'59 CONTINUED ON WSR 09/21/08 Final Tbq. IA. OA -> http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=43 B65 9E4E3... 2/ 15/2009 FLUID SUMMARY _._.__._..__..,_,_....~.__._..________...__.__m..__._.__..~,___..___..,__~,_______..w__._....__n_.__„__M,.,._,__._..._____ 1 BBL DIESEL PT LUB WellServiceReport • . Page 1 of 2 WELL SERVICE REPORT WELL JOB SCOPE UNIT P_06B PRESSURE TEST (INTEGRITY) SWCP #08 DATE DAILY WORK DAY SUPV 9/21/2008 IN PROGRESS; GAS LIFT-TO DUMMY VALVES JONES COST CODE PLUS KEY PERSON NIGHT SUPV PBPPDWL06-I SWCP-FINCH MCGUINESS MIN ID DEPTH TTL SIZE 2.37 " 10909 FT 0 " DAILY SUMMARY ***CONTINUED FROM WSR 09/20/08*** DRIFTED TBG TO DEPLOYMENT SLV @ 9647' MD W/ 4 1/2" BRAIDED LINE BRUSH, 3.75" GAUGE RING SET 4 1/2" XN C-SUB @ 9641' SLM (DEPLOYMENT SLV) /LRS PUMPED 21 BBLS METH ATTEMPTED TO FIND STA#1, COULD NOT EVEN SEE, COVERDED IN CEMENT OR BEHIND LINER. PULLED BK-DGLV's FROM STA's #2, #3, #4, #5 /SET BK-OGLV's IN STA #5 (2967' SLM) & STA #4 (5504' SLM) /SET BK-DGLV's (ext packing) IN STA #3 (7767' SLM) &STA #2 (9267' SLM) CURRENTLY PERFORMING MIT-IA ***CONTINUED ON WSR 9/22/08*** LOG ENTRIES Init Tb IA OA -> 240 380 0 TIME COMMENT 00:15 RIH W/ 2' x 1.875" WB, 3.65" CENT... WORKED TIGHT SPOTS FROM 1100' TO 4800 SLM...STOP @ 5200' SLM...CALL REP...POOH 00:01 CONTINUED FROM WSR 09/20/08 .125 WIRE 5' x 2.625" WB, OJ, LSS 00:02 OOH W/ 4 1/2 XN C-_SUB~OVERED IN SCHMOOy OOmm50 OOH W/ TOOLS (COVERED ON SCHMOO~~ _~ __..._..w _._._._._ __.~...w__~ ~.._.__....._......___._~..__._ __.._.._.._ _..._~_..__. 01:08 RIH W/ 4 1/2 BL6,3.75" GAUGE RING...WORKED TOOLS FROM -900' TO 5010' SLM...TAGGED DEPLOYMENT _S_LV_@__9644' SLM~DE,PLOY SLV ..~ POOH..BRUSH MANDRELS ON WAY_OUT _ _ _ ____ 02:34 RIH W/ 4 1/2 GS, 4 1%2 XN C-SUB...TOOLS FAFALLING SLOWLY FROM 1800' TO DEPLOYMENT SLV...JAR DOWN POOH ~XN C-SUB SET_ ~a 9641' SLM) _ . , 04:22 CALL REP W/ DIFFERENTIAL PRESSURES...STAND BY FOR CALL BACK 04:33 CALL BACK(RIH ATTEMPT TO LATCH STA #1..IF UNABLE PUH AND LATCH STA #2, SDANDBY FOR PUMP _ TRUCK ____ ____ _ .~..a.~_ ~..__~~_______..~.._.~, _.._.,, 04:40 RIH W/ KJ, 4 1/2 OK-6, 1 1/4 JDC...ATTEMPT TO LOC STA #1 THREE TIMES~..PUH TO STA #2, LOC..SD @ _.. 9267' SLM 05:58 BEGIN STANDBY FOR LRS _ 06:35 C/O TO GOVATOS,_INSPEC.T~LOC, HELD~pJSM,_REVIE_WED JSAS &.AWGRS._.______" _.__ M „" _ _., 0647 ,LRS ON LOC,.SPOTTED UP THERE EQUIP, CAME IN SL UNIT FOR PJSM & REVIEW JOB _ 07:0_0 LRS BEGIN RIGGING TO WELL 07:16 LRS BEGIN PUMMPING 07:25 LRS COMPLETED PUMPING 21 BBLS METH ~_._ 07:28 STILL LATCHED TO STA #2 @ 9267' SLM, PULLED THREE 1000# JAR LICKS UP, TOOLS CAME FREE, PULL UP TO 6000', STAND-BY FOR LRS TO RIG OFF WELL, 08:25 LRS LEFT_ LOC / SIBO, OOH W/ STA #2 BK-DGLV 08 38 RIH W/ SAME a 10:28 LOC & S/D ON STA #3 7767' SLM, PULLED TWO 900# JAR LICKS UP, CAME FREE, OOH W/ STA #3 DGLV 10:36 RIH W/ SAME _,________.. _.____._...._____.._..____._..~.~,~v,._...._.____..__. ~..._._..___.._.__.._.___._...____.,_____..___.___._._._.__......____..._......._._______~..__.___~.___w..__..__..._~. 11:20 LOC & S/D ON STA #4 @ 5504' SLM, PULLED 900#, 1000#, 1100# JAR LICKS UP, CAME FREE, OOH W/ STA #4 DGLV 11:34 RIH W/ SAME "_," " ._~6L~~"," 12:36 LOC & S/D ON STA #5 @ 2967' SLM, PULLED THREE 900# JAR LICKS UP, CAME FREE, OOH W/ STA #5 DGLV ....__.___.._,~ ___._...m.~ ,,.._.. ___. _... ~...._......__._______.~..,.,...__. e _.._._ ___._...__..w.__......,...__....___....__.__._.~,__, _ _._.."_,~____.._...._,.._,.____.. ~._._..._. _. ____._,.,._.__.... 12:49 RiH W/ KJ, 4 1/2" OK-6, JK, STA #5 BK-DGLV 13:20 LOC & S/D IN STA #5 @ 2967' SLM, TAPPED DOWN, PERFORMED 900# PULL TEST, OOH W/O STA #5 BK- DGLV 13 33 RIH SAME (STA #4 BK- DGLV) _ ~ _ ~ _ _ 14:29 LOC & ~S/D IN STA #4 @ 5504' SLM, TAPPED DOWN, PERFORMED 900# PULL TEST(PASS), OOH W/O STA #4 BK-DGLV 14 42 RIH W/ SAME STA #3 BK-DGLV~ext Packing" _.m _ _ 15:51 LOC & S/D IN STA #3 @ 7767' SLM, TAPPED DOWN, PERFORMED 900# PULL TEST(PASS).~OOH W/O STA #3 BK- DGLV http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=48BD949C60... 2/ 15/2009 We1lServiceReport • • Page 2 of 2 16:02 RIH W/ SAME, STA #2 BK- DGLV ext ackin `'~_ _ ~, 16:57 LOC & S/D IN STA #2 @ 9267' SLM, TAPPED DOWN FOR 10 MINS, PERFORMED 800# PULL TEST(PASS) PULLED VALVE OUT__OF_PO_CKET TRING TO SHEAR OFF,POOH 17 35 SIBO, O_OH W/ S_TA #2 DG_L_V BOTH SET OF PACKING ON DGLV WERE_RIPPED~_______ _ 18:40 C/O TO D HIGGS. HOLD PJSM, INSPECT LOCATION. REDRESS VALVE AND INSPECT TOOLS. mT~ ........_ ~~~ 19:51 RIH W/ KJ, 4 1/2" OK-6, JK, STA#2 BK-DGLV (w/ extended packing); LOC, S/D ON STA#2 @ 9267' SLM. SPEND _ _ SOME EXTRA TIME SETTING VALVE, POOH. 22:01 OOH W/ TOOLS. VALVE GONE. RIG UP TRIPLEX. 22:3_0 B_E_GIN_MIT-IA. INITIAL T/l/0=20/50/0. PRESSURED UP TO 4000# IN 45 MINUTES, PUMPED 1/2 DIESEL TOTE. 2_3:15 IA PRESSURED UP TO 4000#. TUBING AND OA SAME. 23:59 CURRENTLY PERFORMING MIT-IA. CONTINUE ON 9/22/08 WSR. Final Tba. IA. OA a 20 4000 0 VICE COMPANY -SERVICE SER DAILY COST CUMUL TOTAL _ _ CH2MHILL LABOR $960 $1,920 EQUIPMENT FLEET $2,100 __ __ __._,_$4,200, HLUMBERG SC ER ....._...... ,_ .._rv...... ... __ .,,,_,...$5,802 ..,_.. .. $7,252 _ _ _ ......__~ .~. PERCENT SCHLUMBERGER PLUS 15 .._..... _-$870 ___ ._ __m__. „,____._$1,088 _ . _ WAREHOUSE $0 $4,899 .__._.._.._.._......_.,. _._ Y. _.__.__.__..____._..__,._._._._ .. LITTLE RED PLUS 20 PERCENT $0 _ $345 - LITTLE RED .... -_ $p $1,725 TE: GAS LIFT VALVES GLM GLM VALVE TYPE PORT TRO LATCH COMMENTS NUM DEPTH SIZE TYPE 5 2,985 DUMMY BK 4 5,514 DUMMY BK 3 7,729 .__ DUMMY _ _ ___ BK 2 9 267 DUMMY BK http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=48BD949C60... 2/ 15/2009 We1lServiceReport • • Page 1 of 2 WELL SERVICE REPORT WELL JOB SCOPE UNIT P~06B PRESSURE TEST (INTEGRITY) SWCP #08 DATE DAILY WORK DAY SUPV 9/22/2008 MIT-IA JONES COST CODE PLUS KEY PERSON NIGHT SUPV PBPPDWL06-I SWCP-HIGGS MCGUINESS MIN ID DEPTH TTL SIZE 2.37 " 10909 FT 0 " DAILY SUMMARY "~**CONTINUED FROM WSR 9/21/08*** MIT-IA TO 4000# *PASS* (see data tab for details) PULLED 4 1/2" C-SUB FROM 9641' SLM *EMPTY* *vr* III !`/IAA DI CTC \A/CI 1 I CCT C/I l1A1 f\CDA CTI ICC*** LOG ENTRIES Init Tba. IA. OA -> 20 4000 0 TIME _. COMMENT 00 01 CONTINUED FROM WSR 9-21 08_ CURRENTLY.PERFORMING MIT-IA_TO 4000#. 00:10 BEGINNING TEST T/I/0=20/4000%0. IA LOST 20 PS! 1ST 15 MIN., AND 20 PSI 2ND 15 MIN.***PASS***. RIG 00:40 BLEED IA DOWN ADJACENT FLOWLINE TO 0 PSI. ~_,._.__ ~._ __,__._.._..___.._.__.._..._.__..~....,....__._.w_.,..._.__....._._._..,___._.._._,____..~..__..___._._ _.._ 01:30 RIH W/ 4 1/2" GS. CO REP ON LOCATION TO COLLECT AWGRS. S/D ar? 9641' SLM, LATCH CATCHER, POOH. ,_03:23_ OOH W/ TOOLS, CATCHER RECOVERED. CALL PE. HOLD PJSM. 03:45 BEGIN RIGDOWN. SWAB S/I, WING S/I, SSV OPEN (fusible cap), MASTER OPEN, CASING VALVES OPEN TO GAUGES. *PAD OP UNABLE TO INSPECT LOCATION AT THIS TIME, OK TO MOVE OVER* 05:00 RIG DOWN COMPLETE. MOVE OVER TO WELL 26. END TICKET. Final Tho_ IA. OA -> 20 0 0 SERVICE COMPANY -SERVICE DAILY COST, .._.__._._~ _ CUMUL TOTAL,________w CH2MHILL LABOR ... $960 $2,880„ EQUIPMENT FLEET $2 100 $6 300, SCHLUMBERGER __. ... .__~_, .__.._$1E209 _...._-.., .._..,._._ _., _ _..._$8,461 __._. _. ___..__._._._..____ ~ ~ SC~HLUMBERGER PLUS 15 PERCENT ~ ~ _..___.... ......_„_.. , $181 $1,269 .~__...__.____v___,._______._......_ __._._._.. __. _..~..___._ WAREHOUSE ....... .... . . ............__.._.. .,,_..._,...,_$864 _...... ~..._..,. ...$5763.. _.__._,__.___.___._._~_.._,_.....___.__.___,_ .._._..._._~,.._ ._..___......., . PERCENT LITTLE RED PLUS 20 _.._..._ __ ... ...... ......._..... ..-_..__._$0 _._.._...______.___ _.._......$~5 _ _ __..__.__. __...~_.. ._.___, _ LITTLE RED _ ._._._._. $0_ $1,725 TOTAL FIELD ESTIMATE: I $5,314 ~ $26,743 FLUID SUMMARY ***18 BBLS DIESEL FOR MIT-IA*** GAS LIFT VALVES GLM GLM VALVE TYPE PORT TRO LATCH COMMENTS NUM DEPTH SIZE _ TYPE 5 2,985 ______ DUMMY Y____.._. 0 ..___._..__ 0 BK ._..______ __.._._.....__ .............._........__.._._._.. ., __... _.. _..__._ 4 _...__ 5,514 __.._._,,~.. DUMMY _____0 0 BK 3 7,729 DUMMY 0 __ _0 .___BK EXTENDED PACKING____, __ 2 9,267 DUMMY 0 0 BK EXTENDED PACKING http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=F2C34F 11 CB... 2/15/2009 We1lServiceReport • Page 2 of 2 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=F2C34F 11 CB... 2/ 15/2009 We1lServiceReport • • .Page 1 of 1 WELL SERVICE REPORT WELL JOB SCOPE UNIT P-OGA ANN-COMM (REG COMPL) LRS 42 DATE DAILY WORK DAY SUPV 1 /21 /2009 MIT-IA SAUVAGEAU COST CODE PLUS KEY PERSON NIGHT SUPV PBPPDWL06-I LRS-ZIMMERMAN SPIELER MIN ID DEPTH TTL SIZE 0" 0 FT 0" DAILY SUMMARY T/I/0=425/920/210 Temp =110*F AOGCC MITIA PASSED to 3000 psi (Witnessed by C. Sheave) Pressured up IA with 2 ~% bbls meth. IA lost 30 psi in the 1st 15 mins and 10 psi in the 2nd 15 mins for a total pressure loss of 40 psi in 30 min test. Bled IA. FWHP's=425/920/180. Swab =shut, Master =oxen, Wing =open, IA =open and tagged, OA =open IA I OA 17:30 Start Ticket 17:35 On location. Permitted. Rid u~ PJSM _~_ ~ ~~40 ......_._ ._.~.__.._. ..._._ _. ...__......._.__ _.....___._.._. ,. _ ___._... PT to 3500 ___.~. __.__.._ ..~ , _ 17:44 . _ 0.5 ...._~__._..._ St .. , Meth 425 920 210 Start down IA 17:51 2.7 425 _ '3000 / 410 Shut down. Start Test. ~ ......_ ~__.._.. .... ~_. 18 06 425 2970 410 15min pressures. _ ____ _, 18:21 425 X2960 x410 30min pressures PASS Bleed down. 18:31 425 920 180 Ri down. Final-> 425 920 180 ~' PWI REQUIRED TEST PRESSURE TEST TYPE FLUIDS USED TO TEST 3,000 MIT-IA METH START TIME: 17:51 _ _ PRE TEST ~_ INITIAL 15 MINUTE 30 MINUTE PASS OR FAIL PRESSURES PRESSURES PRESSURES PRESSURES TUBING 425 425 425 425 IA 920 _._.~ ........ 3,000__ ......_...~_...-_ _2,970 ..~.......... 2,960 _......_,..._.._....._ PASS .._.. ._._.__... ...._..,,, _._...___ ._.~.. OA ....... 210 410 410 410 http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=08E698431 C2... 2/ 15/2009 FLUID SUMMARY ~2.7bbls meth .._......_ __..~__.,......._...___._...~ _ __.. ..... .._... ._.._._.._._„ , TREE= 4-1116" CNV WELLHEAD = 5M FMC ACTUATOR OTIS KB. ELEV - _ 77.90' BF. ELEV - 55.41' ~_-~ _ .m,~.m KOP ~~m~ _...~ 4 x'00' Max Angle= 103 ~ 10573' Datum MD = 9964' DatumTVD = _ 8800' SS 10-314" CSG, 45.5#, NT-80, !D = 9.950" 2$8T Minimum ID = 2.37" @ 10909' TOP OF 2-7/8" LN R ~3-1/2" LNR, 8.81#: L-80 STL; .0087 bpf, ID= 2.990" ~TOPOFS-112" LNR, 17#, 13-CRJ-~ 9739' 4-1l2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 9742' 7-5/8" CSG, 29.7#, NT-95-HS, ID = 6.875" I-i 9966' WHIPSTOCK (10113105} 9974' ELM TOP OF 2-7/8" LNR. ID = 2.37" 999$' CIBP (10(09/05} 10025' 2-7l8" LNR, 6.5#, L80, .00579 bpf, ID = 2.37" (~ 12130' PERFORATION SUMMARY REF LOG: MWDlEWR(SGRC!SROP ON 10125/05 ANGLE AT TOP PERF: 80 @ 10925' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10925 - 11050 O 10!27105 2" 6 11490 - 11530 O 10/27105 3-3/16" LNR, 6.2#, L-80 TGII, .0076 bpf, ID = 2.80" SAFNOTES: ORIGINAL WELL {P-06} IS NOT SHOWN ON RAM. ***CH OME4-112'°TBG*** 2103' -j4-112" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2985 2985 0 CAMCO DMY BK 0 09/21J08 4 5514 5481 25 CAMCO DMY BK 0 09!21(08 3 7729 7224 39 CAMCO *DMY BK 0 09/21!08 2 9267 8389 43 CAMCO *DMY BK 0 09/21(08 1 9636 8654 44 CAMCO **DMY BK 0 11!03/05 . 51 A #Z Zfc 7#3 = IJM Y'S tiAV E t7C 1 t:Nt3tD PRGKING **MANDREL COVERIDw1CEMENT {10120105 DIMS} 9647' 3.70" DEPLOY SLV, ID = 3.00" 9$64' 4-112" PKR SWS NIP, ID = 3.813" (BEHIND PIPE) 9666' 3-1(2" HES X NIP, ID = 2.813" 967T 7-5/$" X 4-1!2" TMJ HBBP PK .,,_,.,..,,,,...^ ( EHIND PIPE) ' 9699 ~ - 3-112" X 3-3116" XO, iD - 2.867" 970$' - 4-1(2" PKR SWS NIP, ID = 3.813" {BEHIND PIPE} 9731' 4-1/2" PKR 5WN NIP; MILLED TO 3.80" (BEHIND PIPE) 9739' 7-5l8" X 5-1/2" T!W LNR HGR W/TBS (BEHIND PIPE} 9743' 4-112" WLEG, ID = 3.958" {BEHIND PIPE} NOTE: TAILPIPE HAS BACKED OFF & IS RESTING ON 5-1/2" LNR TOP MILLOUT WINDOW (P-066} 9974' - 9982' 10909' (-~ 3-3116" X 2-718" XO, ID = 2.441 " ~ 10909' I PBTD 11561' 3.70" BKR RETRIEVALBE BP w!SUPPORT PIPE TO TD 11596' 2-718" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" 11597' TD 11800' DATE REV 8Y COMMENTS DATE REV BY COMMENTS 05123!91 SJA ORIGINAL COMPLETION 10/17/08 MBIV1/PJC GLV Cl0 (fl9/21(08} 12/25/97 PARKER CTD SIDETRACK (P-06A} _ 10/29/05 NORDIC1 CTD SIDETRACK {P-066) 11/D3/05 DAVlTLH GLV Ci0 12/05/05 DAV/TLH DRLG DRAF7 CORRECTIONS 08/27/06 JCNUPAG GLV CIO P-06B I PRUDHOE BAY UNfI• WELL: RO66 PERMIT No: 2051380 Aft No: 50-029-22166-02 SEC 31, T11N, R13E, 2506' FSL & 1963' FWL BP Exptoration {Alaska} MEMORANDUM • State Of Alaska • Alaska Oil and Gas Conservation Commission TO: ~ DATE: Wednesday, January 28, 2009 Jim Regg P.I. Supervisor ~~~~ f ~ Zlti~ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC P-06B FROM: Chuck Scheve YRUDHOi: BAY UNIT P-06B Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.1. Suprv ~~-- Comm Well Name: PRUDHOE BAY UNIT P-O6B ~ API Well Number: 50-029-2216v-oz-oo Inspector Name: Chuck Scheve Insp Num: mitCS090 1 220 83 909 Permit Number: zos-138-o Inspection Date: li2-i2oo9 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. __.._ . , _ _ i_..YP J _ __ __- _ P-06B W T~ 8683 '~ .IA 920 3000 .~ 2970 2960 ,~ Well T e In'. P.T. zosl3so TypeTest SPT Test psi zno.7s J OA ~ 2io aIO aio a1o Interval REQvAR P/F P -~ Tubing ~ azs azs azs azs NOtes• Pretest pressures observed and found stable. f Wednesday, .lanuary 28, 2009 Page I of I ,`, n ~ DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2051380 Well Name/No. PRUDHOE BAY UNIT P-066 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22166-02-00 MD 11800 TVD 9033 Completion Date 10/28/2005 Completion Status 1-OIL Current Status 1WINJ IC Y REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD / EWR / SGRC / SROP Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments ~D D Asc Directional Survey D C Lis 15305 Gamm,a..Ray i , ~,v-acv I, Rpt 15305 LIS Verification I ~" ~~~ r ~,.~ ~ ~ v~'~ " C Lis 15401 Gar~rna-f=ay T,,.~~~ 9953 11800 Open 11/17/2005 Definitive 9950 11800 Open 8/3/2007 LIS Veri, GR, ROP, FET w/Graphics 9950 11800 Open 8/3/2007 LIS Veri, GR, ROP, FET w/Graphics 9950 ~t8nn _Op®n 8!'il2QIIZ .L!S Veri Oi.B, R!~° `~T w/Gsa~ics 9950 11800 Open 9/12/2007 LIS Veri, GR, ROP, FET w/Graphics **COPY** Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? ~'f~ Daily History Received? \\~ N Chips Received? ' Y / N Formation Tops' ~~~iV///// Analysis '(-,~-Pd~ Received? Comments: Compliance Reviewed By: I ~ Date: __~0 t, ~'`~~ ~wv WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : P-06B August 15, 2007 AK-MW-4005436 P-06B: Digital Log Images: 50-029-22166-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchora e, Alaska 99518 Anchorage, Alaska 99508 F 'J a ~~~~ n7 Date: w ~ . ~~ ~ ~, / Signed: "~:~`~ ~~i~ WELL LOG TRANSMITTAL To: State of Alaska July 31, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: P-06B, AK-MW-4005436 1 LDWG formatted CD rom with verification listing. API#: 50-029-22166-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 .. ~ ~, M ~~° ~ a j e Date: ~ ~ ,~~~~ Signed:~!__ Y~iL/ ~:. j~s :~ ~,: r.~ r~?C~r~`"~~ ~ =c ~ ~~-_ l 3 ~S i t s ~bs' • d 0 ~ o d SARAH PALIN, GOVERNOR ~~7~ Oui ~D ~ 333 W. 7th AVENUE, SUITE 100 C01~5ERVATI011j COM11II55I01~ ANCHORAGE, ALASKA 99501-3539 PHONE {907} 279-1433 FAX (907) 278-7542 ADMINISTRATIVE APPROVAL AIO 3.015 Mr. Steve Rossberg, Wells Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99519-6612 RE: PBU P-06B (PTD 205-138) Request for Administrative Approval Dear Mr. Rossberg: in accordance with Rule 9 of Area Injection Order 003.000, the Alaska Oil and Gas Con- servation Commission ("AOGCC" or "Commission"} hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. PBU P-06B exhibits tubing-casing annulus (inner annulus) repressurization. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU P-06B and is able to manage the inner annulus pressure with pressure bleeds. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, PBU P- 06B exhibits two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to inject water only in PBU P-06B is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 3. BPXA shall perform aMIT - IA every 2 years to 1.2 times the maximum antici- pated well pressure; 4. BPXA shall limit the well's IA pressure to 2000 psi; • AIO 3.015 March 13, 2007 Page 2 of 2 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection; and 7. The M1T anniversary date is January 19, 2007. 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 consid- ered 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. DONE at Anchorage, Alaska and dated March 13, 2007. Cathy P. Foerster Com ssioner , ~ e,~ t } ~eh~!• ~ ~ ` , d ~ r 1~ y ,' ~~ ' , ,'1 ~ -, ).. ` ~, ~fy '~ i ' F ~ f i . ~~. l ~ f , J~, t I ^~ ~ ~ ., XS i~,. ~~ _ +~ i~ ' , a % ~i ~' ~ ` •si t~~ ` ` t _ . . ._ . ~~' 1 i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~(/~,{ I ~~''~ Mechanical Integrity Test •`~T ~~ Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein~admin.state.ak.us; Jim_Regg@admin.stale.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU / P pad DATE: 01 /19/07 OPERATOR REP: Jack Winslow AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well P-06B Type In'. W TVD 8,662' Tubing 500 500 500 500 Interval O P.T.D. 2051380 Type test P Test si 3000 Casing 1,030 3,000 2,990 2,990 P/F P Notes: MIT-IA for evaluation. OA 30 3D 30 30 Well Type In'. TVD Tubing Interval P.T.D. T etest Test si Casing p/F Notes: OA Well T In'. TVD Tubing Interval P.T.D. T pe test Test psi Casing p/F Notes: OA Well Ty a Inj. TVD Tubing Interval P.T.D. T pe test Test si Casin p/p Notes: OA Well Type In'. TVD Tubing Interval P.T.D. Type test Test psi Casin p/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I = Inftial Test G =Gas P =Standard Pressure lest 4 =Four Year Cycle I =Industrial Wastewater R = Intemal Radioactive Tracsr Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT PBU P-066 01-19-07-1.xls MEMORANDUM i--, To: Jim Regg ~~~~ 1~ ~? ~ ~ 4> P.I. Supervisor ~ I ERO~I: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commissio DATE: Wednesday, November O1, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC P-06B PRUDHOE BAY UNIT P-06B 5rc: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~~~ Comm Well Name: PRUDHOE BAY UNIT P-06B Insp Num: mitCS061028062418 Rel Insp Num API Well Number 50-029-22 i66-02-00 Permit Number: 205-138-0 Inspector Name: Chuck Scheve Inspection Date: 10/27/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - ~ Well ~, P-o68 EType Inj. ; w ~~ TVD s6s3 IA 600 ~ zsoo zszo ~~ zszo ~ ~ -- ' -- - ' ~05t380 ~ SPT ~ -- P.T. i - TypeTest ~ Test psi - X17075_ - -- I OA loo I Iso I - 180 I80 ~ ' - - - - Interval ~IT~- P/F P ,%' Tubing Iso Iso ~~ 7so Iso NOtes Well recently converted from producer to injector. Pretest pressures were observed and found stable. Wednesday, November O1, 2006 Page 1 of t ~~++ cc ~ / C STATE OF ALASKA ~ ~ ~ T 1 n ZOOa ALASKA OIL AND GAS CONSERVATION COMMISSION RFPIf~RT [1F CI IAlI1RY WGI I It1PFR~TIfiGI! & Gas COtls. C~rrlfssil~ri 1. Operations Performed: Abandon Repair Well Plug Perforations^ Stimulate ^X OtherO After Casing Pull Tubing Perforate New Pool Waiver Time E xtension Change Approved Program Operatio n Shutdown Perforate ~ Re-enter Suspended Well 2. Operator gp Exploration (Alaska) Inc. 4. Current Well Class: 5. Permit to Dril l Number: , Name: Development ~ Exploratory 205.1 8 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic~ Service~X 50-029-22166-02-00 7. KB Elevation (ft): 9. Well Name and Number: 92.10 P-06A 8. Property Designation: 10. Field/Pool(s): ADL-028288 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 11800 feet true vertical 9033.0 feet Plugs (measured) None Effective Depth measured 11581 feet Junk (measured) None true vertical 9024.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 120 20" 91.5# H-40 63 - 183 63.0 - 183.0 1490 470 SURFACE 2625 10-3/4" 45.5# N-80 62 - 2687 62.0 - 2687.0 5210 2480 PRODUCTION 9905 7-518" 29.7# NT95HS 61 - 9966 61.0 - 8893.0 8180 5120 LINER 237 5-112" 17# NT13Cr80 9739 - 9976 8728.0 - 8900.0 7740 6280 LINER 52 3-1/2" 8.81# L-80 9647 - 9699 8662.0 - 8699.0 10160 10530 LINER 1210 3-3/16" 6.2# L-80 9699 - 10909 8699.0 - 8997.0 8520 7660 LINER 891 2-7/8" 6.16# L-80 10909 - 11800 8997.0 - 9033.0 13450 13890 Perforation depth: Measured depth: 10925-11050, 11490-11530 True vertical depth: 8999-9024, 9028-9025 Tubing (size, grade, and measured depth): 4-1/2" 12.6# 13CR80 @ 58 - 9743 Packers &SSSV (type & measured depth): 7-518" TIW HBBP Packer @ 9677 4-112" Otis SSSV Nipple @ 2103 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Infection Data Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: ExploratoryQ Development Service~X Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ X Oil Gas WAG ~ GINJ~ WINJ~X WDSPL~ Prepared by DeWayne R. Schnorr (907) 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr• 306-332 Printed Name DeWay a R. Schnorr Title Petroleum Engineer Signature Phone 564-5174 Date 10/18/06 Form 10-404 Revised 4/2004 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure --- -- SI --- --- °- --- SI --- --- • • P-06A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/02/2005 (pre flow test) SET 4 1/2" X C-SUB (NO KEYS) AT 9621' SLM, PULLED DGLV'S FROM STA #3 AT 7729', STA #4 AT 5514', AND STA #5 AT 2985' & ATTEMPTING TO PULL STA# 2 AT 9267'. *** JOB IN PROGRESS *** 11/03/2005 (pre flow test) PULLED DGLV FROM STA # 2 AT 9242' SLM, SET DOME GLV IN STA # 5 AT 2985' MD (16/64 TRO 1780 BK LATCH) SET DOME GLV IN STA # 4 AT 5514' MD (16/64 TRO 1750 BK LATCH) SET DOME GLV IN STA # 3 AT 7729' MD (16/64 TRO 1720 BK LATCH) SET S/O GLV IN STA # 2 AT 9267' MD (22/64 BK LATCH) PULLED CATCHER SUB (FULL OF CEMENT CHUNKS), RETURNED WELL TO PAD OP. ****WELL LEFT SHUT IN **** 12/07/2005. New Well Pop and Test Corrected Gross Fluid Rate 512.5 STBFPD Corrected Oil Rate 344.5 STBOPD Corrected Formation Gas Rate 0.697 MMSCFPD Net Water Rate 168 BWPD GOR 2024 SCF/STB Lift Gas Rate 2.70 MMSCFPD 06/17/2006 T/I/O = 230/1070/10. 85 deg. IA FL (pre AOGCC MITIA). Well on AL gas. IA FL @ 9267' (Sta # 2 SO). 243 bbls. No integral. 07/21/2006 ***WELL SHUT IN ON ARRIVAL**** DRIFT TUBING W/3.50" CENT TO DEPLOY SLV @ (9647' MD) 9620' SLM ***27' CORRECTION*** RAN SBHPS AS PER PROCEDURES ***GIVE WELL BACK TO DSO, LEFT SI*** 08/25/2006 ***WELL SHUT IN ON ARRIVAL*** (gl maint -pre inj conversion) RIG UP SLICKLINE UNIT FOR GASLIFT WORK. 08/26/2006 CLEAR TIGHT SPOT IN TUBING W/3.85 GUAGE RING SET WHIDDON @ 9585'SLM PULL OGLV FROM STA #2, PULLED LGLV FROM STA #3, #4 & #5. SET 1"DGLV IS STA'S: #5, 4, & 3 CURRENTLY SETTING UP TO LOAD IA AND TEST. 08/27/2006 (gl maint -pre inj. conversion) LRS COULD NOT PUMP DOWN IA, PERFS PLUGGED OFF. VECO RAN LOOP FROM TBG ON P-06 TO P-27 FLOW LINE. LRS PUMPED 5 BBL NEAT METH, 160 BBL INHIB. SEA WATER, 75 BBL NEAT METH. SET 1"DGLV IN STA #2 @ 9228'SLM. UNABLE TO GET GOOD MIT-IA DUE TO OUT OF FLUID PULLED CATCHER @ 9585' SLM. NOTE:--- LRS WILL RETURN LATER TO COMPLETE MIT-IA. 08/27/2006 T/I/0=2400/1900/VAC Assist slickline. Attempt to MIT IA. Load IA with 122 bbls of inhibited 1%KCL. Tubing and IA locked up, let sit for 2 hrs tried to pump again, pushed 19 bbls of inhibited 1 % and it locked up again. Let sit for 1.5 hrs, tried to pump again, pumped 13 bbls of neat methanol, well locked up again. slickline PE Decided to take returns down P-27 flowline. Bled Tx IAP down, Pump remaining KCL 30 bbls followed by 58 bbls of neat meth. slickline to set DGLV, use remaining 10 bbls of neat methanol to attempt to reach test pressure. No pressure increse. RDMO Final WHP's = 1350/vac/0+ 08/28/2006 TIO = 1550/980/0. Temp = SI. IA FL (for FB). IA FL @ 1680' (44 bbls). No AL. Page 1 • • P-06A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/04/2006 T/I/0= 2000/910Nac. Temp= Cold. Bleed IA < 500 psi (pre-MITIA). IA FL @ 1788'. Bled IAP down well 5 from 910 psi to 420 psi in 1 hour. Monitored for 30 minutes. No change in pressures. IA FL @ 1620' (42 bbls). Final WHP's= 2000/420Nac. 09/05/2006 T/I/0= 2100/480/0. MIT-IA to 2500 psi. [Failed 3 tests] Lost 80 psi / 1st 15 min and 80 psi / 2nd 15 min. TBG pressure increased slowly during the tests. LLR is too small for this pump to measure. Pumped 53.4 bbls of 76* crude to achieve test pressure. Well was on injection upon arrival but not taking fluid. Well was shut in during this test. Final WHP= 2425/500/20. 10/11/2006 ***WELL S/I ON ARRIVAL*** (pre ctu fco/acid stim) suspect ice plug) R/U SLICKLINE UNIT. 10/12/2006 (pre ctu fco /acid stim) DRIFT W/ 2.25" CENT & S. BAILER, SD @ 1696' SLM (BAILER FULL OF WHAT APPEARS TO BE SCHMOO & HYDRATES) ***WELL LEFT S/I*** 10/14/2006 CTU #6, Ice Plug /Injectivity Test; MIRU unit. 10/15/2006 CTU #6, Ice Plug /Injectivity Test; Cont' from WSR 10/16/06 ... MU and RIH with 2.0" DJN. Tag ice at 278'. Jet hard ice with 60/40 and neet meth down to 402'. Tag another hard bridge at 1743' and jet ice down to 1883'. Cont' RIH. Sat down at 11036' ctmd. Jet through bridge. Sat down again at 11480' ctmd, feels like lock-up. PUH, losing ground. Perform injectivity test, achieved 1.4 bpm with WHP at 1865 psi and steadily climbing. Circulate in 2% KCL w/ 0.6% SafeLube. Work coil to hard bottom at 11539' ctmd. Wash perfs with 20 bbls of 12% DAD acid as per program. Saw good initial indication of pert break down. Pull above 2 7/8" liner section. Perform injectivity test; Injectivity = 1.5 bpm @ 1830 psi WHP (WHP slowly climbing). Injectivity = 1 bpm @ 1415 psi WHP (WHP flat). POOH. Well left shut in with 60/40 FP to 2500'. *** Job Complete *** 10/16/2006 Inj Press, psi: Type: PW Vol: FLUIDS PUMPED BBLS 3 Diesel --- PT Surface E ui ment 68 Neet Methanol 333 60/40 Methanol Water 90 Methanol 54 Crude 171 1%KCL Water- Inhibited 188 2% KCL Water 103 2% KCL Water with 0.6% Safe Lube 20 12% DAD Acid 1030 TOTAL Page 2 TREE = 4-1/16" CNV WELLHEAD = 5M FMC ACTUATOR = OTIS KB. ELEV = ~~ 77.90' BF. ELEV = 55.41' KOP = 4900' Max Angle = 103 @ 10573' Datum MD = 9964' Datum N D = 8800' SS 10-314" CSG, 45.5#, NT-80, ID = 9.950" I~ 2687' Minimum ID = 2.37" @ 10909' TOP OF 2-7/8" LNR 13-1/2" LNR, 8.81#, L-80 STL, .0087 bpf, ID = 2.990" I~ 9699' ~TOPOFS-1/2" LNR, 17#, 13-CR 4-112" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 7-518" CSG, 29.7#, NT-95-HS, ID = 6.875" i-1 9966' WHIPSTOCK (10/13/05) 9974' ELM TOP OF 2-718" LNR, ID = 2.37" ~ 9998' CIBP(10/09/05) 10025' 2-7/8" LNR, 6.5#, L80, .00579 bpf, ID = 2.37" I~ 12130' PERFORATION SUMMARY REF LOG: MWD/EWR/SGRC/SROP ON 10!25/05 ANGLE AT TOP PERF: 80 @ 10925' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE 2" 6 10925 - 11050 O 10!27!05 2" 6 11490 - 11530 O 10(27/05 SA NOTES: ORIGINAL WELL (P-06) IS NOT SHOWN P _0 ~ ~ ON DIAGRAM. CHROME 4-1 /2" TBG ® 2103' -i4-1/2" OTIS SSSV NIP, 10= 3.813" GAS LIFT MANDRELS 3-3/16" LNR, 6.2#, L-80 TCII, .0076 bpf, ID = 2.80" ST MD ND DEV TYPE VLV LATCH PORT DATE 5 2985 2985 0 CAMCO DMY BK 0 0$!27/06 4 5514 5481 25 CAMCO DMY BK 0 08/27/06 3 7729 7224 39 CAMCO DMY BK 0 08/27/06 2 9267 8389 43 CAMCO DMY BK 0 08!27106 1 9636 8654 44 CAMCO **DMY BK 0 11/03/05 *"MANDREL GOVERI~w/CEMENT (10/20/05 DIMS) 9647' 3.70" DEPLOY SLV, ID = 3.00" 9664' 4-1/2" PKR SWS NIP, ID = 3.813" (BBiIND PIPE) 9666' 3-9/2" HES X NIP, ID = 2.813" 9677' 7-5/8" X 4-112" TNV HBBP PKR (BEHIND PIPE) 9699' 3 1/2" X 33/16" XO, ID = 2.867" 9709' 4-.112' PKR SWS NIP, ID = 3.813" (BEHIND PIPE) 9731' 4-1/2" PKR SWN NIP, MILLED TO 3.80" (BEHIND PIPE) 9739' 7-518" X 5-1 /2" TM/ LNR HGR W/TBS (BEHIND PIPE) 9743' 4-112" WLEG, ID = 3.958" (BEHIND PIPE) NOTE: TAILPIPE HAS BACK® OFF & IS RESTING ON 5-112" LNR TOP MILLOUT WINDOW (P-O66) 9974' - 9982' 10909' 3-3/16" X 2-718" XO, ID = 2.441" I 10909' I PBTD 11561' 3.70" BKR RETRIEVALBE BP w /SUPPORT PIPE TO TD 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" 11 DATE REV BY COMMENTS DATE REV BY COMMENTS 05/23/91 SJA ORIGINAL COMPLETION __ 12125!97 PARKER CTD SIDETRACK (P-O6A) 10/29/05 NORDIC1 CTD SIDETRACK (P-O66) 11/03/05 DAVITCH GLV C/O 12/05/05 DAV/TLH DRLGDRAFTCORRECTIONS 08!27/06 JC(WPAG GLV GO PRUDHOE BAY UNff WELL: R-06B PERMff No: 82051380 API No: 50-029-22166-02 SEC 31, T11N, R13E, 2506' FSL t£ 1963' FWL BP Exploration (Alaska) ,. _ ~~ ,~ ~, ~_ ,~. s n~ ;_. - = FRANK H. MURKOWSKI, GOVERNOR ~-~t7~RA O~ ~ ~ 333 W. T" AVENUE, SUITE 100 COI~TSERQATIOI~T CObIIriISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alice Kaminski Pad Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU P-06B Sundry Number: 306-332 Dear Ms. Kaminski: _ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. n_-- ----_,-- DATED this day of October, 2006 Encl. ~u5 - I3~S STATE OF ALASKA ' * ~ ~KA OIL AND GAS CONSERVATION COM MON. APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~E~~~' 1. Type of Request: Abandon Suspend Operational shutdown Perforate 8S ~ ~i~r ~ Other ~Ot2S, C~-rt(lil$Sit) Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^~ Time Extensior)(}~~OrB~S Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 205-1380 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^w 6. API Number: Anchorage, AK 99519-6612 50-029-22166-02-00 7. KB Elevation (ft): 9. Well Name and Number: 92.1 KB PBU P-06B 8. Property Designation: 10. Field/Pools(s): ADLO-028288 Prudhoe Bay Field Field / Prudhoe Oil Pool Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11800 9033.06 0 0 None None Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H-40 37' 117' 37' 117' 1490 470 Production 9931' 7-5/8" 29.7# NT-95Hs 35' 9966' 35' 8892' 8180 5120 Surface 2651' 10-3/4" 45.5# NT-80 36' 2687' 36' 2687' 5210 2580 Liner 237' 5-1/2" 17# NT13Cr80 9739' 9976' 8728' 8900' 7740 6280 Liner 1210' 3-3/16" 6.2# L-80 9699' 10909' 8699' 8997' 8520 7660 Liner 688' 2-7/8" 6.16# L-80 10909' 11597' 8997' 9024' 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10925 - 11050 8999.37 - 9024.33 4-1/2" 12.6# 13-CR 0 - 9743' 11490 - 11530 9028.4 - 9025.45 Packers and SSSV Type: 4-1/2" TIW HBBP-R PACKER Packers and SSSV MD (ft): 9677' 0 0 0 0 0 0 12. Attachments: Descriptive Summary of Proposal 0 13. Well Class after proposed work: ~,6(sl~ Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Developments' Service [t~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/12/2006 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG 0 GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact glice Kaminski Printed Name Alice Kaminski Title Pad Engineer Signature - "Phone 564-5676 Date 9/28/2006 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test I ~I Location Clearance ^ Other: ~~ L ~ YQ }' ll,LhQ ~ , cJ ~ ~~~- ~ i.~ ~ ~ 1.~~6 Subsequent Form Required: ~ C7 - 4 p APPROVED BY D ~~ ~D~ Approved by: MMISSIONER THE COMMISSION Date: / v~ Form 10-403 Revised 1112004 ®~ I ~ ~ ~ f ~ ] Submit in Duplicate .~. b ; p ~~~ ~~1 ~2: :~~ i~~;~1,~ To: C. Olsen / J. Bixby, GPB Well Ops TL From: Alice Kaminski, P-Pad Engineer Jessica Pedota, Wells Engineer Subject: P-06Bi Jet Ice Plug & Acid Wash Perfs (chrome tbg) AFE: PBPPDWL06-C • Date: Sept 27, 2006 Est. Cost: $60M IOR: 400 Attached is a CT rocedure that includes the followin ma'or ste s: 1 S Drift & to as dee as ossible 2 C Remove ice plug Contin ent acid wash chrome tb ,does NOT re uire se arator Current Status: SI injector, operator notes indicate well is frozen, Flow line is freeze protected Max Deviation: 103 degrees @ 10573' MD Min. ID: 2.37" ~ 10,909' MD, top of liner Last TD tag: No tag since CT sidetrack Last Downhole Ops: Slickline DGLVs and gauge runs on 08/26/06 to 9585' SLM H2S Level: 15 ppm from parent well P-06A on 3/4/02 Well P-06Bi was a coil sidetrack drilled on 10/28/05. Injection after initial perforations was 3 BPM at 3000 psi. The well was pre-produced on gas lift starting Feb 2006 until it was shut-in June 2006. It was converted to a WAG injector to support production wells P-25L1, P-26, and P-11. All GLVs were dummied off on 08/26/06. Post-DGLVs, MIT IA to 2500 psi was attempted on 08/27/06 but they ran out of fluid on location, an~he tubing could not be pumped down suggesting there was an ice plug in the tubing. The well was POI 09/02/06, but they could not inject water. The MIT IA to 2500 psi was attempted three times on 09/05/06 but failed each time on stabilization. The LLR was too small to establish with the pump (80 psi lost in the first 15 minutes and 80 psi. lost in the second 15 minutes). On 09/16/06 the tubing was frozen to the surface but the flowline was freeze protected. After removing the ice plug, a contingent acid wash using a small volume of HCI acid is recommended if the injection obtained is not sufficient. The MIT IA is scheduled to be redone after injection has been established. ~ A small volume contingent HCI acid stimulation is chosen based on similar well P-03Ai's performance after an acid wash 10/3/98. This job used 2 gal/ft of 12% 90:10 DAD acid and increased the injection from 600 bpd at 2400 psi to 1500 bpd. A CoiICADE has been completed and 1.75" CT should have no problems getting to PBTD. If you have any questions or comments regarding this procedure, please call Jennifer Julian at (W) 564-5663, (H)274-0929, (C)240-8037 or Alice Kaminski at (W)564-5676. Use the truck phone to call JJ's cell if you have problems calling from CTU's phone. cc: w/a: Well File • • Well History 09/27/05 MIT OA failed -LLR 2.6 bpm @ 1550 psi 07/25/05: Caliper from P-06Ai - 4.5" tubing is in good condition, max penetration of 24% in Jt 108 @ 4,169'. No other significant wall penetrations, areas of cross- sectional wall loss or ID restrictions are recorded in the 4.5" tubing. 10/29/05: CTD sidetrack P-06B; Injectivity was 4 BPM @ 2400 psi 11!03/05: Pull DGLVs, put in GLVs; failed attempt to change lowest DGLV due to cement rocks 11/29/05: Well was produced for a couple days, 512 BFPD, 344 BOPD, 168 BWPD 02!06-06/06: Well produced for a couple months, starting rate 580 BOPD, 38 BWPD (618 BFPD, 02/15/06), last rate 101 BOPD, 144 BWPD (188 BFPD, 06/27/06) 07/21/06: SBHPS, drift to 10,096' with slickline (no tag) 08/26106: Dummy GLVs, scrape dry paraffin/asphaltenes from 1079'-1209' SLM 08/27/06: Can't pump down tubing 08/28/06: IA FL @ 1680' 09/02!06: POI j 09/05/06: MIT-IA failed, too small for LLR 09/16/06: Operator notes say flow line was freeze protected; tubing is frozen. Pump truck pressured up to 3000 psi immediately. 09/21/06: Bled tubing from 2100 psi to 100 psi when tree jumped and at least 1 ice plug came free. Tubing might not be frozen solid. Stimulation Target Perforations: 10,925' - 10,050' = 125 11,490' - 11,530' = 40 Total Footage 165 feet Perf Deviation: 80-95° Injectivity: None (Tubing frozen) Wellbore Volume: 160 bbl to 11,561' Contingent Acid design: 5 gpf 12% 90:10 DAD acid Fluid Requirements: 20 bbl 12% 90:10 DAD acid Prep Work: 1. RU slickline. Drift and tag as deep as possible. 2. Shoot FLs and fluid pack IA as necessary. Ice plug and contingent DAD Acid Stimulation 3. RU 1.75" CT. Rig up hard line to be able to pump down tubing for injectivity test. Check that the well is still shut in at lateral and wing valves. 4. Jet ice plug with neet methanol. Minimum ID is 2.37" at 10,909' (top of the 2 7/8" liner.) Note: 4 '/z" chrome tubing, use lubetex as necessary, making sure to not inject any lubetex into the formation. • • 5. RIH to tag PBTD to ensure there are no obstructions in the liners. FCO as necessary (not expected.) If fill found, due to cement and paraffin in the past, do not fluff-and-stuff the fill. 6. Monitor the IA pressure during treatment. 7. Pull above the perforations and perform an infectivity test with 2°I° KCI down the CT. Note infectivity on WSR. If injection is less than 2 BPM at 1500 psi (WHP), plan to do acid job (steps 8-11.) Contingent Acid Job Ensure that acid returns are not brought to surface to prevent H2S in returns. / 8. RIH to 11,555'. Spot ~5 bbl of 12% DAD acid at a 1:1 ratio over perforations +/- 25 feet (10900' - 11555') and soak for 30 minutes. 9. RIH to 11,555'. Spot ~5 bbl of 12% DAD acid at a 1:1 ratio over perforations +/- 25 feet (10900' - 11555') and continue pumping another 10 bbl of acid. Soak for another 30 minutes. 10. RIH to 11, 555' and flush all perfs with 15 bbl 2% KCI. Do not POOH until the total overflush volume is behind pipe. 11. Pull above perforations. Perform infectivity test with 2% KCI. Note on WSR. 12. Freeze protect well until MIT-IA is performed. Check acid additive packages for BHST of 214°F and 12 hour protection time for 13Cr. Acceptable acid concentrations +/-1 % for HCI. Fluids should be 90-110°F. 90:10 DAD acid additives A261 Corrosion Inhibitor 0.6% A179 Corrosion Inhibitor 4 t A153 Corrosion Inhibitor 8 t F103 Surfactant 0.2% L58 Iron Control 20 t W54 NonEmulsifier 0.5% W60 Anti-Stud e 0.5°l° U74 Dis ersant 1.5% • • Abbreviated version of very long directional survey: MD (ft) TVD (ft) SS (ft) Inclination Azimuth Dog Leg 4,973 4,970.13 4,878.03 11.65 345.18 3.3 5,171 5,161.68 5,069.58 16.97 351.76 2.0 5,396 5,372.69 5,280.59 22.78 352.11 3.2 5,733 5,677.35 5,585.25 28.48 350.42 1.9 6,124 6,006.96 5,914.86 36.92 350.98 2.5 6,936 6,619.81 6,527.71 42.18 351.33 0.4 7,377 6,951.75 6,859.65 39.67 352.41 0.9 7,733 7,227.45 7,135.35 38.65 . 353.81 0.8 8,085 7,502.14 7,410.04 40.00 358.09 1.1 8,462 7,790.55 7,698.45 39.78 2.51 1.0 8,834 8,073.16 7,981.06 42.10 6.39 1.1 9,205 8,343.84 8,251.74 43.38 10.92 1.1 9,976 8,899.88 8,807.78 43.06 21.35 2.7 9,993 8,912.04 8,819.94 44.41 21.35 8.0 10,021 8,931.35 8,839.25 47.05 21.20 9.6 10,062 8,958.43 8,866.33 52.07 20.91 12.0 10,122 8,991.77 8,899.67 60.26 20.20 14.1 10,154 9,006.50 8,914.40 65.37 16.$5 18.3 10,215 9,028.19 8,936.09 71.43 10.84 9.3 10,249 9,038.05 8,945.95 75.07 1.88 27.3 10,312 9,050.73 8,958.63 80.97 351.13 21.9 10,375 9,056.09 8,963.99 88.90 356.94 16.3 10,409 9,055.67 8,963.57 92.51 2.23 19.0 10,482 9,050.52 8,958.42 94.79 16.65 21.8 10,540 9,041.22 8,949.12 102.47 15.44 9.7 10,605 9,027.07 8,934.97 101.59 3.64 12.9 10,632 9,021.71 8,929.61 100.62 358.35 19.0 10,703 9,008.73 8,916.63 100.09 345.14 12.2 10,761 8,999.42 8,907.32 99.82 334.56 22.6 10,792 8,995.33 8,903.23 95.25 337.33 17.1 ... • 10,824 8,993.80 8,901.70 90.22 338.09 15.9 10,856 8,993.87 8,901.77 89.52 341.08 9.8 10,887 8,995.06 8,902.96 86.17 345.84 18.5 10,916 8,998.06 8,905.96 82.03 348.13 16.1 10,954 9,005.15 8,913.05 76.12 347.78 15.8 10,989 9,013.11 8,921.01 77.80 341.96 16.8 11,027 9,020.53 8,928.43 79.74 335.97 16.3 11,058 9,025.50 8,933.40 81.67 331.92 14.4 11,085 9,028.90 8,936.80 84.14 329.98 11.4 11,122 9,032.53 8,940.43 84.41 324.34 15.4 11,152 9,035.42 8,943.32 84.49 320.82 11.8 11,185 9,039.29 8,947.19 82.38 314.65 19.2 11,222 9,043.06 8,950.96 85.73 312.54 10.9 11,251 9,044.22 8,952.12 89.69 310.25 15.6 11,282 9,043.57 8,951.47 92.69 307.07 13.9 11,315 9,041.85 8,949.75 93.30 304.25 8.8 11,346 9,039.68 8,947.58 94.89 305.84 7.4 11,380 9,036.76 8,944.66 94.98 312.71 20.2 11,415 9,033.80 8,941.70 94.63 319.58 19.4 11,450 9,031.23 8,939.13 93.74 325.40 16.7 11,520 9,026.12 8,934.02 94.36 335.09 18.8 11,554 9,024.59 8,932.49 90.75 334.21 10.8 11,584 9,024.08 8,931.98 91.19 340.55 21.3 11,614 9,023.43 8,931.33 91.28 340.03 1.8 11,646 9,021.98 8,929.88 93.92 334.03 20.6 11,678 9,021.01 8,928.91 89.60 330.16 18.4 11,710 9,022.35 8,930.25 85.73 326.99 15.3 11,743 9,025.22 8,933.12 84.14 324.87 8.1 11,772 9,028.84 8,936.74 81.41 319.94 19.5 11,800 9,033.06 8,940.96 81.41 319.94 0.0 P-06B (PTD #2051380) MITIA form • ~ ~, c~ 1 it 1"tom Subject: P-06B (PTD #2051380) MITIA forni ~~~~ From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> Date: Stan, 10 Sep 2006 21:14:31-0800 To: ",Iim_ Rey>~~ (E-mail)" '_jinr_ r~~ ~~~iadmiil.state.al:.us~,, "~~~ii~to~l Hubert (L-mail)~~ <wimon auhcrt~~r~~admin.state.akus==,'Bob Fleckenstein (E-mail)" .:bob Ileckenstein("u adn~in.state.ak.us-= CC: "NSU, Al~~~' Wcll [nte~rity En<~inecr" ~~NSUr~DWWe111nte~rilyEn~,incer~~iBP.cor~1~~•, „NSU, ADW WI Tech" :~_;~SUAD~V~~'[Te.ch~~r-BP.com==~, "Subekti, Herr~~" ~~tIerr~r.Subekti!"riBP.conl> Jim, Winton, and Bob, Please see the attached MITIA form for the MITIA post conversion to injection for P-06B (PTD #2051380). The wel! was place on injection the days before the test but was not taking water when we arrived to conduct apre-MITIA before inviting the AOGCC. This is seen in a beginning tubing pressure of 2100 psi. The test was attempted three times but failed each time on stabilization. It is suspected ~. that this was due to thermal affects. I've included the MITIA form. «MIT PBU P-06B 09-05-06.x1s» The plan forward for this well is to conduct an acid wash to gain infectivity. Once the well is on injection again, we'll re-test the well and send in the form. Thank you, Anna ~Du6e Well Integrity Coordinator GPB Wells Group Phone: (90T) 659-5102 Pager: (907) 659-5100 x1154 '' Content-Description: MIT PBU P-06B 09-OS-06.x1s ,MIT PBU P-06B 09-05-06.x1s 'Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 9/11/2006 8:52 AM STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. ~ Prudhoe Bay /PBU / P Pad J/ ~ 1~~~ 09/05/06 t Anna Dube Packer Depth Pretest Initial 15 Min. 30 Min. Well P-066 Type Inj. W TVD 8,683' Tubing 2,100 2,500 2,500 2,475 Interval 4 P.T.D. 2051380 Type test P Test psi 2170.75 Casing 480 2,500 2,420 2,340 P/F F Notes: MITIA post conversion to injection OA 0 20 20 20 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle 1 =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT PBU P-068 09-OS-06-1.xls •« ti STATE OF ALASKA ALAS AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 03/08/06: Revised, Put on Production 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended WAG zoAACZS.~os zoAACZS.>>o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 10/28/2005 12. Permit to Driil Number 205-138 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/22/2005 13. API Number 50-029-22166-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 10/25/2005 14. Well Name and Number: PBU P-06B 2506 FSL, 1963 FWL, SEC. 31, 711 N, R13E, UM Top of Productive Horizon: 312' FSL, 1931' FWL, SEC. 30, T11N, R13E, UM 8. KB Elevation (ft): 92.1' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 1800' FSL, 1426' FWL, SEC. 30, T11N, R13E, UM 9. Plug Back Depth (MD+TVD) 11561 + 9024 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 63124 6 y- 5947233 Zone- ASP4 10. Total Depth (MD+TVD) 11800 + 9033 Ft 16. Property Designation: ADL 028288 __ _ __ __ __ TPI: x-_ 631161 y- 5950318 Zone- ASP4 Total Depth: x- 630631 Y- 5951797 Zone- ASP4 11. Depth where SSSV set N/A MD 17. Land Use Permit: ----- ------------------ ------------ f P f 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL erma rost 20. Thickness o 1900' (Approx.) 21. Logs Run: MWD / EWR / SGRC / SROP 2. CASING, LINER AND EMENTING RECORD CASING ETTING EPTH MD ETTING EPTH TVD HOLE OUNT ' SIZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE CEMENTING RECORD PULLED 20" Surface 120' Surface 120' 10-3/4" 45.5# N-80 Surface 2687' Surface 2687' 13-1/2" 939 cu ft Permafrost 7-5/8" 29.7# NT95HS Surface 9967' Surface 8893' 9-5/8" 1461 cu ft Class 'G' 5-1/2" 17# NT13Cr80 9739' 9976' 8728' 8900' 6-3/4" 165 cu ft Class'G' 3-1/2' x 3-3/16' x zaie• e.ai ~ i s.zn i s. i su L-80 9647 11597 8662' 9024' a•ve• x a-va• 146 cu ft Class 'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 9743' 9677' MD TVD MD TVD 10925' - 11050' 8999' - 9024' 11490' - 11530' 9028' - 9025' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Si KIND OF MATERIAL USED 11597' Set Bridge Plug w/ Support Pipe to TD (11800') 2500' Freeze Protect w/ 48 Bbls of Diesel 26. PRODUCTION TEST Date First Production: February 15, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 3/1/2006 Hours Tested 12 PRODUCTION FoR TEST PERIOD OIL-BBL 133 GAS'MCF 131 WATER-BBL 42 CHOKE SIZE 91° GAS-OIL RATIO 980 Flow Tubing Press. 26 Casing Pressure 1,240 CALCULATED 24-HOUR RATE OIL-BBL 266 GAS-MCF 261 WATER-BBL 84 OIL GRAVITY-API (CORK) 23.3 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach ~~ ;,• , . sary). Submit core chips; if none, state "none". None MAR 0 _~ i'11i 1 F~~ ~Fl. MAR ~ ~ 2006 Alaska Ott & Gas C~~ s. y::~~r>r~ussion Anchora~~.~ Form 10-407 Revised 12/2003 ®~ ~ ~ ~ ~ ~O TINUED ON REVERSE SIDE V r-u P- /'1 C 1' t 8. GEOLOGIC MARKER 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Shublik A 9959' 8887' None Shublik B 10018' 8930' Shublik C 10050' 8951' Eileen 10087' 8973' Sadlerochit /Zone 46 10097' 8979' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. / t~Q~ Signed Title Technical Assistant Date ~~/ vv Terrie Hubble PBU P-06B 205-138 Prepared By Name/Number Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. DnllingEngineer: Ted Stagg, 564-4694 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each poo4 completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelty Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". ITeM 29: List ail test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG R~~l~~ ~~V ~~ ~ ~1~8~ Alaska Oil & Gas Cons. Gornmission dnrhnr~s,a 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 10/28/2005 12. Permit to Drill Number 205-138 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/22/2005 13. API Number 50-029-22166-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 10/25/2005 14. Well Name and Number: PBU P-068 2506 FSL, 1963 FWL, SEC. 31, T11N, R13E, UM Top of Productive Horizon: 312' FSL, 1931' FW L, SEC. 30, T11 N, R13E, UM g. KB Elevation (ft): 92.1' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 1800' FSL, 1426' FWL, SEC. 30, T11N, R13E, UM 9. Plug Back Depth (MD+TVD) 11561 + 9024 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 631246 y- 5947233 Zone- ASP4 10. Total Depth (MD+TVD) 11800 + 9033 Ft 16. Property Designation: ADL 028288 TPI: x- 631161 y- 5950318_ Zone- ASP4 Total Depth: x- 630631 Y- 5951797 Zone- ASP4 11 • Depth where SSSV set N/A MD 17. Land Use Permit: ------ ------- - --- f f P t 20 Thi k 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL ness o erma ros . c 1900' (Approx.) 21. Logs Run: MWD / EWR / SGRC / SROP 2. CASING, LINER AND CEMENTING RECORD CASINR EITIN(i EPTH MD ETTINp EPTH,TVD 1~0~ MOUNT $12E WT. PER FT. GRADE OP - T'tOM` OP TTOM uIZE CEMENTING RECORD PULLED 20" Surtace 120' Surtace 120' 10-3/4" 45.5# N-80 Surtace 2687' Surface 2687' 13-1/2" 2939 cu ft Permafrost 7-5/8" 29.7# NT95HS Surface 9967' Surface 8893' 9-5/8" 1461 cu ft Class'G' 5-1l2" 17# NT13Cr80 9739' 9976' 8728' 8900' 6-3/4" 165 cu ft Ciass'G' a-,/z• x 3-ary e• x 2a/e• 8.t,1 # / 6.2R / 6.1sx L-80 9647' 11597' 8662' 9024' a-,/e• x a-,/a• 146 cu ft Class 'G' 23. Pertorations open to Produc tion (MD + N D of Top and " ' 24. TustNG RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 9743' 9677' MD TVD MD TVD 10925' - 11050' 8999' - 9024' 11490' - 11530' 9028' - 9025' 25` ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 11597' Set Bridge Plug w/ Support Pipe to TD (11800') 2500' Freeze Protect w! 48 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Prod~tioNlnjectbn Vet Method of Operation (Flowing, Gas Lift, etc.): N/A (Pre-Produced Injector) Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None _. l d ~ ~y~.b Md" g~~6 ~1'Ib ~~~~ ~ p~ r~ ... ~, Form 10-407 Revised 12/2003 ~..~ ~~ ~ ~ ~~~~rI~IUED ON REVERSE SIDE r-~ 28. GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Shublik A 9959' 8887' None Shublik B 10018' 8930' Shublik C 10050' 8951' Eileen 10087' 8973' Sadlerochit /Zone 4B 10097 8979' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. t ~ Signed Title Technical Assistant Date ` Terrie Hubble ~ a'~l PBU P-06B 205-138 Prepared By Name/Number.• Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Ted Stagg, 564-4694 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Litt, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Operations Summary Report Page 1 of 12 Legal Well Name: P-06 Common Well Name: P-06 Spud Date: 5/6/1991 Event Name: REENTER+COMPLETE Start: 10/18/2005 End: 10/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 10/28/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To ', Hours I Task I', Code NPT Phase ! Description of Operations 10/18/2005 ~ 14:00 - 16:30 ~ 2.50 ~ RIGD P ~ ~ PRE ~ Rig released from W-39A @ 14:OOHrs on 10/18/2005. Unstab 16:30 - 16:45 0.25 MOB P PRE 16:45 - 17:00 0.25 MOB P PRE 17:00 - 18:30 1.50 MOB N RREP PRE 18:30 - 18:45 0.25 MOB N RREP PRE 18:45 - 00:00 5.25 MOB N RREP PRE 10/19/2005 00:00 - 01:30 1.50 MOB N RREP PRE 01:30 - 01:45 0.25 MOB P PRE 01:45 - 14:00 I 12.25 MOB P PRE 14:00 - 15:00 ~ 1.00 MOB P PRE 15:00 - 19:30 I 4.501 RIGU I P i i PRE 19:30 - 22:00 I 2.501 RIGU I P I I PRE 22:00 - 00:00 2.00 RIGU N SFAL PRE 10/20/2005 ~ 00:00 - 00:45 0.751 RIGU N SFAL PRE 00:45 - 01:00 i 0.25 ~ MOB ~ P ~ ~ PRE 01:.00 - 01:30 0.501 MOB P PRE 01:30 - 03:30 2.00 RIGU P PRE 03:30 - 10:30 7.00 BOPSU P PRE 10:30 - 12:45 2.25 BOPSU P PRE 12:45 - 13:00 0.25 ZONISO P ! WEXIT CT. Remove & R/D gooseneck & packoff. Prep to move rig to P-pad. PJSM for moving rig off well Jack-up rig & pull rig off well. Conduct post-operations pad inspection. Prepare rig for fire change out. Remove stairs & landing. PJSM for changing out tire. Change out off-driller's side rear inside tire. Meanwhile changeout injector chains. Finish changing out tire. Install stairs & landing. Held pre-move safety meeting with crew, security & tool services. Move rig from W-pad to P-pad. Arrive C~ P-pad. Discuss surface close proximity of P-27 with ANC. P-27's wellhouse was removed for rig access on P-06. Depressurize P-27 AL line to header pressure (300psi). P-27 is a Cat-2 well with no SSSV. There are no annular communication problems & the tree has been bled down to LP. Attempt to bled off 50psi WHP on P-06 - no success. Call out LRS for load & kill. PJSM. install gooseneck & pack-offs. Stab CT. RU & cut 500' of CT for fatigue managment. Also changing out washed out HCR control valve on koomey. Meanwhile W.O. Little Red Pumping Services to arrive onsite. Little Red Pumping Services arrive pad. Conduct PJSM for P-06A well kill. MIRU pumping equipment & hardline on P-06. Open up well & observe 50psi WHP, Opsi IAP & Opsi OAP. Load/kill well by bullheading 5bbls of McOH spacer ahead, 290bb1s seawater & 5bbls McOH spacer behind at max rate. Observe max infectivity of 5bpm C~ 2900psi. WHP dropped to 50psi after pump S/D. Bled down WHP to Opsi. Meanwhile P/U BOP stack & install X/O flange. Continue changing out washed out HCR control valve on koomey. Continue changing out washed out HCR control valve on koomey. Need koomey to operate the front boosters. Finish changing out washed out HCR control valve on koomey. PT valve OK. PJSM. Review procedure, hazards. & mitigation for backing rig over well. Back rig over well & set down. Accept rig C~3 01:30Hrs on 10/20/2005. N/U BOPE. Grease tree & choke manifold valves. Meanwhile Pad operator put P-27 back on production. Perform initial BOPE pressure/function test witnessed by AOGCC Inspector John Crisp. Meanwhile fill rig pits with 1% KCL-water. R/U hardline to tiger tank & P/test to 4000psi. Dart coil: 56.4 bbl coil volume. Pressure/pull test CTC. Pressure test inner reel valve. PU cmt. BHA Printed: 10/31/2005 11:40:18 AM BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: P-06 Common Well Name: P-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To ~! Hours ~ Task ~, Code '~ NPT _! - _ ~ -- 10/20/2005 113:00 - 15:15 2.25 ZONISO P 15:15 - 16:45 1.50 ZONISO N DPRB 16:45 - 19:00 2.25 ZONISO N DPRB 19:00 - 21:15 2.25 ZONISO N DPRB 21:15 - 21:45 0.50 ZONISO P 21:45 - 22:30 0.75 ZONISO P 22:30 - 22:45 I 0.251 ZONISO I P 22:45 - 00:00 I 1.251 ZONISO I P 10/21 /2005 00:00 - 00:10 0.17 ZON I SO P 00:10 - 00:25 0.25 ZONISO P 00:25 - 01:00 0.58 ZONISO P 01:00 - 01:45 0.75 ZONISO P 01:45 - 04:10 2.42 ZON1S0 P 04:10 - 04:30 0.33 ZONISO P 04:30 - 05:00 0.50 ZONISO P 05:00 -05:30 0.50 STWHIP P 05:30 - 06:00 0.50 STWHIP P 06:00 - 08:30 I 2.501 STWHIPI P 08:30 - 18:00 9.501 STWHIPI P Spud Date: 5/6/1991 Start: 10!18/2005 End: 10/28/2005 Rig Release: 10/28/2005 Rig Number: N1 Phase I Description of Operations WEXIT RIH to 9746'. Tag, hook load dropped. Tagged multiple at different speeds and pump rates. Couldn't work past obstruction. POOH for stiffer BHA. WEXIT POOH for stiffer BHA. WEXIT LD BHA #1. PU BHA #2. WEXIT RIH with cmt nozzle BHA #2. Wt check @ 9600': Up - 42.5k, Down - 26.5k. RIH into 5-1/2" Tbg to 9800' WEXIT PUH 3x to 9700' (into 4-1/2" Tbg) & RBIH to 9800' to ensure no restrictions. WEXIT Continue RIH & tag WS 2x @ 9996'. Correct CTD to 9974' (ELMD). PUH 10' to 9964' & flag CT. Meanwhile RU triplex pump to IA & bump up IAP to 500psi. RU SLB Cementers. WEXIT PJSM with all personnel concerning cementing operations. Meanwhile continue circulating wellbore @ 0.94/0.66bpm & 143psi to liquid pack wellbore. WEXIT Prime up. Flush/PT lines to 4k. Mix & pump 15.3bbls 15.8 ppg class 'G' cmt slurry & 5bbls of water behind @ 2.85/2.40bpm & 1500psi. Chase with KCL water @ 2.62/2.27bpm & 1750psi. With cmt !bbl from nozzle. Shut-in choke. Bullhead 7.5bbls of cmt away @ 1.25bpm from 20psi to squeeze pressure of 1000psi. Open up choke. Lay-in remaining 7.8bbls cmt 1:1 to TOC @ 9588'. WEXIT POOH to safety @ 9000'. Shut-in choke. WEXIT Hesitate squeeze 5x from 500psi to 1000psi final squeeze pressure. Squeeze in additional 5.ibbls of cmt. WEXIT Hold final squeeze pressure of 1000psi while circ down bio-KCL fluid to the nozzle @ 1.6/1.6bpm & 1700psi. WEXIT RBIH contaminating cmt to 9964ft with 3.25bpm/1550psi. Make 3 down & 2 up passes. WEXIT Jet OOH chasing contamintaed cmt. Jet thoroughly across jewelries & GLMs. WEXIT OOH. PJSM. S/B injector. L/D cement nozzle BHA. M/U swizzle stick & stab injector on well. SI master valve. WEXIT Jet BOP stack & surface lines @ max rate. WEXIT P/U injector & changeout packoff. Cut CT & install Baker CTC. Pull test to 35k & pressure test to 3500psi. WEXIT M/U window milling BHA #3 with a 3.80" HC DP0261 DWM, 3.80" diamond string reamer, Baker straight Xtreme motor, MHA & 2 jts of PH6 tbg (OAL - 81.35'). M/U injector. WEXIT RIH to pinch pt. Reciprocate over tubing tail. No problems. Tag at 9982.9'. Correct to ELM 9974'. Flag pipe at 9974' bit depth-closest flag to gooseneck. WEXIT Mill 3.80" window in 13CR 5.5" tubing. Pressure off btm: 2000 psi O in/out: 2.5-2.7/2.5-2.7. WOB: 1 K Ib - 3K Ib. 7/8 fUhr. Exit into formation @ 9982'. Printed:.10/31/2005 11:40:18 AM BP EXPLORATION Operations Summary Report Page 3 of 12 Legal Well Name: P-06 Common Well Name: P-06 Spud Date: 5/6/1991 Event Name: REENTER+COMPLETE Start: 10/18/2005 End: 10/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 10!2812005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours ! Task II Code ~ NPT Phase ',; Description of Operations 10!21/2005 18:00 - 19:00 1.00 STWHIP P WEXIT Mill 10' formation to 9992' with 2.5/2.5bpm, 1850/1950psi, 6fph ave ROP & 2k WOB. 19:00 - 19:45 0.75 STWHIP P WEXIT Backream/dress window/rat hole 3x & drift 2x. Window looks clean. Tentative window depths are: TOWS/TOW = 9974', BOW = 9982'. 19:45 - 20:30 0.75 STW HIP P WEXIT Swap wellbore to reconditioned (65% used/35% new) 8.6 ppg Flo-Pro mud with 3% L-T & 14ppb K-G. 20:30 - 22:30 2.00 STWHIP P WEXIT Paint EOP flag @ 9800' & POOH window milling BHA #3, while displacing well to mud. 22:30 - 23:30 1.00 STWHIP P WEXIT PJSM. L/D BHA #3 & inspect mills. Window mill & string mill gauge 3.80" go ! 3.79" no-go. Wear on window mil! face indicated center crossed the liner wall. 23:30 - 23:45 0.25 STWHIP P WEXIT Held PJSM for cutting CT. 23:45 - 00:00 0.25 STWHIP P WEXIT R/U hydraulic cutter & cut 150' of CT for chrome-Tbg management. Have 14930' of CT left on the reel. 10/22/2005 00:00 - 00:30 0.50 DRILL P PROD1 Behead & M/U SLB CTC. Pull test to 35k & pressure test to 3500psi - OK. 00:30 - 00:45 0.25 DRILL P PROD1 Held pre-spud safety meeting. Reviewed well plan, potential hazards & drilling BHA M/U procedures. 00:45 - 03:00 2.25 DRILL P PRODi M/U drilling BHA #4 with 1.2deg X-treme motor, MWD/GR-RES, orienter & new Hughes 3-3/4" x 4-1/8" RWD2ST bicenter bit #2. Scribe tools. Initialize RES tool & M/U injector. 03:00 - 05:20 2.33 DRILL P PROD1 RIH drilling BHA#4. SHT MWD &orienter - OK. Continue RIH to 9800'. PUH to 9700' (into 4-1/2" Tbg) &RBIH to 9850' to ensure no restrictions. 05:20 - 05:45 0.42 DRILL P PROD1 Orient TF to LOHS &RIH clean thru window with pumps down. Tag btm with pumps on @ 9993'. Correct CTD to 9992'. 05:45 - 06:00 0.25 DRILL P PROD1 Orient TF to HS. 06:00 - 10:00 4.00 DRILL P PROD1 Drill f/ 9992-10032'. PU wt: 39K Ib. ,SO wt: 22.5K Ib., On btm: 23K Ib. O: 2.7!2.7 bpm Pressure off/on btm: 3300 psi/3350 psi. Correct +2' based on GR tie-in. 10:00 - 18:10: 8.17 DRILL P PROD1 Drill f/ 10032 - 10100'. PU wt: , SO wt: , On btm: 20.8K Ib. O: 2.. 65-2.7512.65-2.75 Pressure off/on btm: 3150-3250 psi/3300-3500 psi. Tough drilling. Motor stalls at >200 psi differential. TF: 0-12R 18:10 - 18:15 0.08 DRILL P PROD1 Short wiper to restart MWD tool. Up wt = 37k. Run-in wt = 27k, IAP = 250psi & OAP = 220psi. PVT = 315bb1s. 18:15 - 20:50 2.58 DRILL P PROD1 Drill to 10150' with 20L-30L TF, 2.57/2.57bpm, 3150/3450psi, 3k WOB & 20fph ave BOP. Seems to have drilled out of the Shublik. 20:50 - 21:35 0.75 DRILL P PROD1 Drill to 10189' with 40L-50L TF, 2.57/2.57bpm, 3150/3450psi, ~ 3k WOB & 50fph ave BOP. 21:35 - 21:55 0.33 DRILL P PROD1 Wiper trip clean to the window. RBIH to btm. 21:55 - 22:20 0.42 DRILL P PROD1 Orient TF around to 70L. 22:20 - 00:00 1.67 DRILL P PRODi Drill to 10233' with 60-80L TF, 2.57/2.57bpm, 3150/3450psi, 4k WOB & 30fph ave BOP. 10/23/2005 00:00 - 02:20 2.33 DRILL P PROD1 Drill to 10315' with 60-80L TF, 2.55/2:55bpm, 3150/3450psi, 4k WOB & 30fph ave BOP. Printed: 10/31/2005 11:40:1 S AM • BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To P-06 P-06 REENTE NORDIC NORDIC Hours R+COM CALIST 1 Task PLET A Code E , NPT Start Rig Rig i ' Phase Spud Date: 5/6/1991 : 10/18/2005 End: 10/28/2005 Release: 10!28/2005 Number: N1 Description of Operations 10/23/2005 02:20 - 02:25 0.08 DRILL P PROD1 Short wiper to restart MWD tool. Up wt = 39k. Run-in wt = 23k, IAP = 320psi & OAP = 300psi. PVT = 309bb1s. 02:25 - 02:40 0.25 DRILL P PROD1 Drill to 10321' with 80L TF, 2.55/2.55bpm, 3150/3550psi, 3k WOB & 50fph ave ROP. 02:40 - 02:55 0.25 DRILL P PROD1 Orient TF around to 40R. 02:55 - 03:40 0.75 DRILL P PROD1 Drill to 10350' with 50R TF, 2.55/2.55bpm, 3150/3550psi, 2k WOB & 50fph ave ROP. 03:40 - 04:00 0.33 DRILL P PROD1 Wiper trip clean to the window. RBIH to btm. 04:00 - 04:45 0.75 DRILL P PROD1 Drill to 10376' with 60-75R TF, 2.55/2.55bpm, 3150/3550psi, 2k WOB & 50fph ave ROP. Observe SLB depth encoder not working. 04:45 - 05:15 0.50 DRILL N RREP PROD1 Change out bearing on SLB depth encoder. RBIH & reset CTD to 10376'. 05:15 - 08:15 3.00 DRILL P PRODi Drill to 10480' with 60-75R TF, 2.55/2.55bpm, 3i50l3550psi, 2k WOB & 45fph ave ROP. Land well @ +/-10396'. Pit 301 bbl. 08:15 - 08:45 0.50 DRILL P PROD1 Wiper trip to window. 08:45 - 09:00 0.25 DRILL P PROD1 Tie-into GR spikes. Correction: +3'. 09:00 - 09:15 0.25 DRILL P PROD1 RIH to TD. 09:15 - 09:40 0.42 DRILL P PROD1 Orient TF to 60R. Only getting 10 degree clicks. 09:40 - 10:00 0.33 DRILL P PROD1 Drill f/ 10500' - 10528'. Pressure off/on btm: 3150 psi/3550 psi-3650 psi. O in/out: 2.55/2.55 bpm 10:00 - 10:20 0.33 DRILL P PROD1 Orient TF to 90L. Only getting 10 degree clicks. 10:20 - 11:15 0.92 DRILL P PROD1 Drill f/ 10528' - 10562'. Pressure off/on btm: 3200 psi/3700 psi. O in/out: 2.6/2.6 bpm. Pits: 290 bbl. 11:15 - 11:45 0.50 DRILL P PROD1 Orient TF 90L Difficulty orienting. 10 degree clicks, mixed with some 25+ degree clicks. 11:45 - 12:30 0.75 DRILL P PROD1 Drill f/ 10562' - 10593'. Pressure off/on btm: 3300 psi/3800-3900 psi. O in/out: 2.7/2.7 bpm. SO wt: 20K Ib., WOB: 6000K Ib. Pits: 292 bbl. 12:30 - 14:00 1.50 DRILL P PROD1 Drill f/ 10593' - 10651'. Pressure off/on btm: 3300 psi/3850 - 4050 psi. O in(out: 2.7(2.7 bpm SO wt: 20.5K Ib, PU wt: 38K Ib. ,Drilling wt: 16.5K Ib decreasing to 13K-12K Ib., WOB: 5K Ib-7.5K Ib increasing to 9K Ib - 10.5K Ib. Pits: 290 bbl. Difficult orientation. 14:00 - 14:20 0.33 DRILL P PROD1 POOH 100' to get oriention. Get 1 click. ' RIH. 14:20 - 14:45 0.42 DRILL P PROD1 Drill f/ 10651' - 10678'. Pressure off/on btm: 3200 psi/3550 psi. O in/out: 2.6/2.6 bpm. Printed: 10/31 /2005 11:40:18 AM BP EXPLORATION Operations Summary Report Page 5 of 12 Legal Well Name: P-06 Common Weli Name: P-06 Spud Date: 5/6/1991 Event Name: REENTER+COMPLETE Start: 10/18/2005 End: 10/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 10/28/2005 Rig Name: NORDIC 1 Rig Number: N1 Date j From - To 'Hours Task ;Code' NPT j Phase I, Description of Operations - 'I -- r -, ~ - - -- 10/23/2005 114:20 - 14:45 0.421 DRILL ~ P I PROD1 ~ Drilling wt: 16.5K Ib - 18K Ib., WOB 6K Ib - 5K Ib 14:45 - 15:00 I 0.251 DRILL V P 15:00 - 15:45 0.75 DRILL P 15:45 - 18:10 2.42 DRILL P 18:10 - 18:50 0.67 DRILL P PROD1 18:50 - 20:35 1.75 DRILL P PROD1 20:35 - 21:10 0.58 DRILL P PROD1 21:10 - 21:20 0.17 DRILL P PROD1 21:20 - 21:50 0.50 DRILL P PROD1 21:50 - 22:05 0.25 DRILL P PROD1 22:05 - 22:40 0.58 DRILL P PROD1 22:40 - 00:00 1.33 DRILL P PROD1 10/24!2005 00:00 - 02:05 2.08 DRILL P PROD1 02:05 - 02:20 0.25 DRILL P PROD1 02:20 - 03:10 0.83 DRILL P PROD1 03:10 - 04:10 1.00 DRILL P PROD1 04:10 - 05:25 1.25 DRILL P PROD1 05:25 - 06:15 0.83 DRILL P PROD1 06:15 - 07:20 1.08 DR1LL P PROD1 07:20 - 07:45 0.42 DRILL P PROD1 07:45 - 08:40 0.92 DRILL P PROD1 08:40 - 09:00 0.33 DRILL P PROD1 09:00 - 10:15 1.25 DRILL P PRODi Pits: 288 bbl TF: 90L. POOH 100' to get orientation Get 1 click. RIH, no change in orientation. Wiper trip to window. Drill f/ 10678' - 10760'. Pressure off/on btm: 3250 psi/3800-3900 psi. O in/out: 2.7/2.7 Drilling wt: 17K Ib-18K Ib, WOB: 6K Ib-3K Ib. Pits: 281 TF: 125E rolling to 110L. Difficulty orienting: sporadic 10 deg. clicks. Orient TF around to 140R. Up wt = 38k. Run-in wt = 22k, iAP = 600psi & OAP = 460psi. PVT = 280bb1s. Drill to 10818' with 140-170R TF, 2.6/2.6bpm, 3300/3750psi, 4k WOB & 35fph ave ROP. Stacking wt. Short wiper & shoot off-btm survey. Getting bad MWD decoding. Drill to 10822' with 160R TF, 2.6/2.6bpm, 3175/3400psi, 8k WOB & 35fph ave ROP. Stacking wt. Wiper trip clean to the window. Up wt = 37k. Log up & tie-into formation marker- add 2' to CTD. RBIH to btm tagged @ 10820'. Run-in wt = 21 k. Drill to 10870' with 125R TF, 2.6/2.6bpm, 3250/3400psi, 8k WOB & 35fph ave ROP. Meanwhile swap the well to fresh 8.6 ppg Flo-Pro mud with 3%'L-T & 8ppb K-G. Drill to 10951' with 140-160R TF, 2.6/2.6bpm, 3250/3400psi, 4-8k WOB & 40-100fph ave ROP. Orient TF to 90L. Up wt = 38k. Run-in wt = 22k, IAP = 500psi & OAP = 330psi. PVT = 303bb1s. Drill to 11000' with 80-90L TF, 2.6/2.6bpm, 2950/3350psi, 3k WOB & 100fph ave ROP. Wiper trip clean to the window. RBIH to btm. Drill to 11079' with 50-75L TF, 2.6/2.6bpm, 2950/3350psi, 3k WOB & 40fph ave ROP. Drill to 11138' with 50-75L TF, 2.6/2.6bpm, 2850/3150psi, 3k WOB & 120fph ave ROP. W iper trip to window. Orient to 60L TF. Drill f/ 11138' - 11192'. Pressure off/on btm: 2850 psi/3250 psi. Q 2.55 in/2.55 out: bpm. TF: 60L going to 90L. Pits: 288 bbl. Orient to 45L TF. Drill f/ 11 i 92' - i 1275'. Pressure off/on btm: 2850 psi/ 3500 psi. PU wt: 38.6K Ib, SO wt: 20K Drilling wt: 14K - 19K Ib, WOB: 2.5K Ib - 7K Ib. O in/out: 2.6/2.6bpm. TF: 55-60L. PROD1 PROD1 PROD1 Printed: 10/31 /2005 11:40:18 AM BP EXPLORATION Page 6 of 12 Operations Summary Report Legal Well Name: P-06 Common Well Name: P-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date .From - To Hours ~ Task Code~NPT 10!24/2005 09:00 - 10:15 1.25 DRILL P 10:15 - 11:45 1.50 DRILL P 11:45 - 12:30 0.75 DRILL P 12:30 - 13:30 1.00 DRILL P 13:30 - 13:50 0.33 DRILL P 13:50 - 15:30 1.67 DRILL P 15:30 - 16:50 1.33 DRILL P 16:50 - 1720 0.50 DRILL P 17:20 - 17:55 0.58 DRILL P 17:55 - 18:05 0.17 DRILL P 18:05 - 18:15 0.17 DRILL P 18:15 - 18:30 0.25 DRILL P 18:30 - 18:50 0.33 DRILL P 18:50 - 19:20 0.50 DRILL P 19:20 - 21:00 1.67 DRILL P 21:00 - 21:15 0.25 DRILL P 21:15 - 21:45 0.50 DRILL P 21:45 - 22:00 I 0.251 DRILL I P 22:00 - 22:20 0.33 DRILL P 22:20 - 22:50 0.50 DRILL P 22:50 - 22:55 0.08 DRILL P 22:55 - 23:15 0.33 DRILL P 23:15 - 23:50 I 0.58 I DRILL I P Spud Date: 5/6/1991 Start: 10/18/2005 End: 10/28/2005 Rig Release: 10/28/2005 Rig Number: N1 Phase Description of Operations PROD1 Pits: 280 bbl. PROD1 Wiper trip to window. Tie-in: +4' correction. RIH. PROD1 Orient TF to 90L. PROD1 Drill f! 11275' - 11335'. Pressure off/on btm: 2950 psi/3450 psi. PU wt: ,SO wt: 20K Ib. Drilling wt: 16-10K {b., WOB: 6K Ib - 9K Ib. O in/out: 2.7/2.7 bpm. TF: 90-100L. Pits: 272 bbl. PROD1 Orient TF to 90R. PROD1 Drill f/ 11335' - 11450'. Pressure oft/on btm: 2950 psi/ 3450 psi. PU wt: 398.5K Ib, SO wt: 19.5K Ib. Q in/out: 2.66/2.66 bpm. TF: 110R Pits: 269 bbl. PROD1 Wiper trip to window. PROD1 Drill f/ 11450' - 11490'. Pressure off/on btm: 2950 psi/3550 psi. Drilling wt: 14.5K Ib - 17K Ib., WOB: 4.5K Ib - 6K Ib. Q in/out: 2.55/2.55 bpm. TF: 70 R. Plts: 261 bbl. TF swinging around. Possible fault. PRODi Orient TF to 80R. PROD1 Drill f! 11490' - 11510'. Pressure off/on btm: 3000 psi/ 3500 psi. Drilling wt: 13.5K Ib - 18K Ib, WOB: 5K - 9K Ib. Q in/out: 2.6/2.6 bpm. TF: 90R. PROD1 Orient TF to 120R. PROD1 Drill f/ 11510' - 11550'. PROD1 Orient TF around to 90R. PROD1 Drill to 11600' with 80-90R TF, 2.6/2.6bpm, 3200/3550psi, 5-9k WOB & 90fph ave ROP. PVT = 257bb1s. PROD1 Wiper trip clean to the window. RBIH to btm. PROD1 Orient TF to 90L. PROD1 Drill to 11649' with 90L TF, 2.6/2.6bpm, 3200/3650psi, 4k WOB & 90fph ave ROP. Encounter lost circulation @ 11649'. Call for additional flopro mud & 2% KCL water. PROD1 Drill to 11661' with 90L TF, 2.6/1.4bpm, 3200/3650psi, 4k WOB & 100fph ave ROP. PROD1 Orient TF to 140L. PROD1 Drill to 11686' with 150-160L TF, 2.5/1.Obpm, 3200/3650psi, 10k WOB & 60fph ave ROP. PROD1 Orient TF to 110L. PROD1 Drill to 11708' with 100-115L TF, 2.4/0.25bpm, 3100/3550psi, 3k WOB & 80fph ave ROP. PVT = 100bb1s. Decide to POH into 5-1/2" Lnr & W. O. additional fluids. PROD1 Wiper trip clean to the window. PUH to 9960' (into 5-1/2" Lnr). Printed: 10/31/2005 11:40:18 AM BP EXPLORATION Operations Summary Report Page 7 of 12 Legal WeII Name: P-06 Common Well Name: P-06 Spud Date: 5/6/1991 Event Name: REENTER+COMPLETE Start: 10/18/2005 End: 10/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 10/28/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From - To I Hours ~ Task I Code NPT Phase j Description of Operations 10/24/2005 123:50 - 00:00 ~ 0.171 DRILL ~ N ~ DPRB ~ PROD1 ~ S/D pumps & W.O. fluids. Meanwhile review situation with ANC 10/25/2005 00:00 - 00:15 00:15 - 01:00 01:00 - 01:30 01:30 - 01:45 01:45 - 01:50 01:50 - 02:00 02:00 - 02:55 0.251 DRILL N 0.75 DRILL P 0.50 DRILL P 0.251 DRILL P 0.08 DRILL P 0.17 DRILL P 0.92 DRILL P 02:55 - 03:15 I 0.331 DRILL 1 P 03:15 - 03:35 0.331 DRILL P 03:35 - 03:45 0.17 DRILL P 03:45 - 04:15 0.50 DRILL N 04:15 - 04:35 0.33 DRILL P 04:35 - 05:10 0.58 DRILL P 05:10 - 05:45 0.58 DRILL N 05:45 - 06:45 1.00 DRILL P 06:45 - 08:30 I 1.751 DRILL I P 08:30 - 11:00 I 2.501 LCR I P 11:00 - 12:00 I 1.001 DRILL I P 12:00 - 13:30 I 1.501 DRILL f P DPRB PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DPRB ~ PROD1 PROD1 PROD1 DPRB PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 & agree to attempt to drill 200' past the loss zone before re-evaluating the plan forward. Continue W.O. fluids. Flopro arrive onsite. RBIH & set down @ 10880'. P/U & bounce thru. RIH to btm. Orient TF around to 130L. Geo wants to target 8970' sstvd C«~ 12100'. Drill to 11720' with 150E - LS TF, 2.4/0.25bpm, 2700/3200psi, 5k WOB & 60fph ave ROP. Orient TF to 100L. Up wt = 40k. Run-in wt = 20k. IAP = Opsi: OAP = 90psi. Drill to 11725' with 135-145L TF, 2.4/0.5bpm, 2900/3400psi, 9k WOB & 30fph ave ROP. Orient 2 clicks & drill to 11753' with 115-155L TF, 2.410.5bpm, 2900/3400psi, 9k WOB & 35fph ave ROP. Switch to 120degs 2% KCL after pumping 200bb1s of mud. Orient 2 clicks & drill to 11770' with 115-130L TF, 2.4/0.5bpm, 2700/3100psi, 9k WOB & 50fph ave ROP. Pumping 20bbls flopro sweep after every 100bb1s of 2% KCL pumped. Orient 2 clicks & drill to 11777 with 110-120L TF, 2.85/0.35bpm, 2500/2900psi, 9k WOB & 25fph ave ROP. Orient 1 click & dri11 to 11782' with 90L TF, 2.8/0.35bpm, 2350/29050psi, 9k WOB & 30fph ave ROP. Stacking wt. Short wiper. Pull heavy @ 11710'. Line up & pump via the back side @ 1.7bpm/800psi. Work CT & pull free with 80k. Wipe up hole to 11500'. RBIH to btm. Orient TF to 80L. Drill to 11800' with 70L TF, 2.8/0.35bpm, 2350/29050psi, 9k WOB &50fph ave ROP. Plan to PUH in the 5-112" Lnr, shut in choke & bullhead 2x wellbore volume to flush wellbore cuttings into loss zone. Wiper. Pull heavy @ 11710'. Line up & pump via the back side Q 2.3bpm/1000psi. Work CT & pull free with 70k. Continue wipping up hole while squeezing down the CT & backside @ 1.7bpm/884psi. Wiper to tubing tail. Wait on orders. Decision made to call TD @ 11800'. RIH & tie-in to GR spike at window. Correction +3'. Begin bullhead operation. POOH C~3 6 fUmin. Pump down backside/coil: 2.4512.4 bpm. Paint flag at 9900' EOP. Pump 2 x 30 bbl Flo-Pro. Last Flo-Pro pill at fracture. POOH to 6000' @ 40 ft/min. Pump down coilfbackside watching for pressure increases. O coil/annulus: 0.5/2.3 bpm. No returns/pressure increase. Continue POOH pumping down the CT Q 2.15bpm/0.15bpm & 1100psi. Printed: 10/31/2005 11:40:18 AM BP EXPLORATION Page 8 of 12 Operations Summary Report Legal Well Name: P-06 Common Well Name: P-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date ~ From - To I Hours ~~, Task i Code I NPT 10!25!2005 ~ 13:30 - 15:00 ~ 1.501 DRILL ~ P 15:00 - 15:45 I 0.75 I CASE I P 15:45 - 16:30 I 0.751 CASE I P 16:30 - 16:45 ~ 0.25 ~ CASE ~ P 16:45 - 17:45 ~ 1.00 ~ CASE P 17:45 - 21:00 I 3.251 CASE I P 21:00 - 21:45 I -0.751 CASE I P 21:45 - 22:15 ~ 0.50 ~ CASE ~ P 22:15 - 00:00 1.75 CASE P 10/26/2005 00:00 - 01:00 1.00 CASE P 01:00 - 02:00 I 1.001 CASE 1 P 02:00 - 06:00 ~ 4.00 CASE ~ P 06:00 - 08:00 I 2.001 CASE I P 08:00 - 08:30 I 0.501 CASE I P 08:30 - 10:00 1.501 CASE ~ P 10:00 - 10:30 I 0.501 CASE I P 10:30 - 10:45 I 0.251 CEMT I P 10:45 - 12:30 I 1.751 CEMT I P Spud Date: 5/6/1991 Start: 10/18/2005 End: 10/28/2005 Rig Release: 10/28/2005 Rig Number: N1 Phase Description of Operations PROD1 OOH. PJSM. S/B injector. Download RES tool. UO drilling BHA. Bit grades - 6/2/1 with a slight ring on the pilot. Meanwhile pump across the WHD to keep the hole full. RUNPRD Load out tool & bring in Baker tools via the elavator. R/U floor for P/U Baker RBP. RUNPRD Cut CT. Install Baker CTC. Pull test to 35k & pressure test to 3500psi ~ OK. RUNPRD Held PJSM for M/U &RIH Baker Retrievable bridge plug BHA#5. RUNPRD M/U BHA#5 with guide shoe, 6jts of 2-7/8" Lnr, Baker Retrievable bridge plug (pinned with steel), R/tools, 2 jts of 2-3/8" PH6 & MHA. M/U injector. RUNPRD RIH with BHA#5, tag btm at 11,805', pumping down the CT @ 0.15bpm/100psi & down the backside @ 1.35bpm/135psi. No problems running through backed off 4 1/2" tailpipe Corrected depth of -12.8' at 9900' EOP, up wt 43 k, do wt 21 k RUNPRD Drop and Circ down 1/2" ball at 2 bpm, 750 psi, returns at 1.15 bpm, reduced rate to .80 bpm, i 50 psi, no returns, set bridge plug at 11596' w/ 950 psi, sheared off w/ 1700 psi RUNPRD PU to 11795', brk circ at 2 bpm 1350 psi, returns at 2 bpm, Displacing well to Flo-Pro pump pressure increased as flo-pro rounded corner 2 bpm w/ 2525 psi RUNPRD POH, Displacing well to Flo-Pro at 2 - 1.8 bpm 2500 - 1900 psi w/full returns, painted flags at 9600 'and 7800' RUNPRD POH, Well displace to Flo-Pro w/full returns, LD two joints of PH6 and Baker R/tool RUNPRD Install volume dart inside reel, install dart connector, Pump volume dart, calculated volume = 57.7 bbls, actual dart displacement = 54.8 bbls, recovered dart, set back inj head RUNPRD PJSM. RU handling tools, power tongs, PU, RIH w/ 2 7/8" x 3 3 1!16" x 3 1/2" Liner Assy, Fill pipe half way through, stab injector RUNPRD RIH with liner, circ at .20 bpm 220 psi. Correct CTD -15.4' @ 1st flag. Wt check: Up = 47k. Run-in wt = 24k. Continue RIH smoothly @ 40 fpm thru window. See 2nd flag 0.5' off. Tag TD @ 11591' CTD. P/U @ 45k. RBIH @ & retag TD @ same depth. Correct CTD to 11596.9'. RUNPRD Establish circ. Load 5/8" steel ball &circ with @ 2.7/2.7bpm & 2000psi. Set down 10k down on CTLRT. Continue circ ball to seat. Slow down @ 41 bbls away. Ball on seat @ 47bbls. Pressure up to 2950psi & release CTLRT. P/U @ 38k & confirm release. RUNPRD Circ well to 2% KCL water with double friction reducer @ 3.0212.93bpm & 2350 psi. Send used FloPro to MI for reconditioning. Meanwhile R/U SLB cementers. RUNPRD Fill rig pits with KCL. Mix 30bbls of 2# biozan displacement fluid. Meanwhile continue displacing well to 2% KCI at 2.53/2.35bpm & 1600psi. RUNPRD PJSM with all personnel concerning cementing operations. Meanwhile continue circulating 2% KCI @ 2.53/2.35bpm & 1600psi. RUNPRD Batch mix 30bbls 15:8ppg 'G' latex cmt with additives. Cmt to wt @ 11:OOhrs. Flush/PT lines to 4k. Pump 26bbls cmt slurry Printed: 10/31/2005 11:40:18 AM BP EXPLORATION Page 9 of 12 Operations Summary Report Legal Well Name: P-06 Common Well Name: P-06 Spud Date: 5/6/1991 Event Name: REENTER+COMPLETE Start: 10/18/2005 End: 10/28/2005 Contractor Name: NORDIC CALISTA Rig Release: 10/28/2005 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To Hours ~ Task ~ Code ~~ NPT ~' Phase ~~ Description of Operations 10/26/2005 10:45 - 12:30 1.75 CEMT P RUNPRD ~ 2.05/1.86bpm & 1900psi. Close inner reel valve & clean lines. Load/launch CTW P with 500psi. Chase with 30bbls bio-KCL ~ 2.72/2.48bpm & 1650psi. CTWP engage LWP C~3 55.4bbls away. Shear plug with 3600psi. Continue displacing LWP @ 1.47/1.38bpm, 1750psi & bump C~3 68bbls away with 1000psi over. Bleed off & check floats -held. Pressure up to 500psi & sting out of liner. 22.5bbls cmt pumped around shoe. CIP C~ 12:30hrs. 12:30 - 14:15 1.75 CEMT P RUNPRD Circ 1bb1 of bio-KCL @ 0.5bpm on TOL. POOH Q 100fpm pumping @ 0.55bpm to replace CT voidage only. 14:15 - 15:00 0.75 CEMT P RUNPRD OOH. PJSM. L/D CTLRT. 15:00 - 15:15 0.25 CEMT P RUNPRD R/U hydraulic cutter & cut 150' of CT for chrome-Tbg management. Have 14780' of CT left on the reel. 15:15 - 15:30 0.25 CEMT P RUNPRD Install SLB CTC. Pull test to 35k & pressure test to 3500psi OK. 15:30 - 16:00 0.50 BOPSU P RUNPRD Conduct weekly BOP function test. 16:00 - 16:15 0.25 CLEAN P RUNPRD PJSM on P/U &RIH liner cleanout motor/mill & 1-1/4" CHS tbg. 16:15 - 18:00 1.75 CLEAN P RUNPRD P/U cleanout BHA #7 with 2.30" D331 mill, 2-118" straight motor, lower MHA, XO, 64jts of 1-1/4" CSH tbg, XO & upper MHA. M(U Injector. 18:00 - 20:30 2.50 CLEAN P RUNPRD RIH with cleanout BHA#7 to landing collar at 11561', pumping 1.5 bpm w/ 1350 psi, returns showed cement contaminated mud from liner top 20:30 - 22:50 2.33 CLEAN P RUNPRD Circ hole clean w/ 30 bbl flo-pro sweep followed by 2% KCL H2O filtered to 5 microns at 1.7 bpm w/ 2900 psi, up wt 41 k, s/o wt 22 k, UCA lab report shows 500 psi compressive strength in 5 314 hours and 2000 psi in 8 1/3 hours. 22:50 - 00:00 1.17 CLEAN P RUNPRD Pump and spot 16 bbls of bleach pill across pert area in liner w/ 2 % filtered KCL H2O at .3 bpm w/ 300 psi, POH, circ filtered 2 KCL H2O at 1.25 bpm w/ 1500 psi 10/27/2005 00:00 - 03:00 3.00 CLEAN P RUNPRD POH, circ 2 % filtered KCL at 1.25 bpm w/ 1500 psi, rack back 1 1/4" CSH, LD motor and mill, Loaded pipeshed with 28 pert guns 03:00 - 03:40 0.67 CLEAN P RUNPRD MU jet swirl nozzle, stab injector, jet stack w/ 3.2 bpm at 2950 psi, RD nozzle, set back injector 03:40 - 04:30 0.83 EVAL P LOW ER1 RU to lubricator, pressure test liner lap to 2000 psi for 30 minutes, pressure fell to 1900 psi, lost 75 psi in first 15 minutes, lost 25 psi in the last 15 minutes. Bled off pressure to 0 psi. Consult with town Engineer Ted Stagg to test liner lap to 3000 psi. 04:30 - 06:30 2.00 EVAL P LOWERI RU on IA with triplex pump, pressured up on IA to 1100 psi, testing liner lap to 3100 psi for 30 minutes, pressure dropped off to 2800 psi, checked surface lines and equipment found drip from HCR valve. Will retest liner lap after circ through coil to move fluid. 06:30 - 07:45 1.25 EVAL N SFAL LOWERI Circ CT for 15mins. Shut-in both master & swab valves & body test the BOP stack & tree as follows: Time WHP CTP IAP OAP Onset 11 0 1028 0 0 3000 0 1025 0 10 2428 0 1021 0 20 2278 0 1013 0 Grease lock both swab & master valves. Printed: 10/31/2005 11:40:18 AM BP EXPLORATION Operations Summary Report Legal Well Name: P-06 Common Well Name: P-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date ~ I Code NPT From - To Hours Task 10/27/2005 ~ 07:45 - 08:50 ~ 1.08~EVAL ~ N ~ SFAL 08:50 - 10:00 I 1.171 EVAL I N I SFAL 10:00 - 11:00 I 1.001 EVAL I N I RREP 11:00 - 11:45 ~ 0.75 ~ EVAL { N {SFAL 11:45 - 12:00 0.25 PERFO~ P 12:00 - 12:15 0.25 PERFO P 12:15 - 13:30 1.25 PERFO P 13:30 - 14:15 I 0.751 PERF0l3l P 14:15 - 16:25 I 2.171 PERFOBI P 16:25 - 17:15 I 0.831 PERFOBI P 17:15 - 18:00 1 0.751 PERFOBI P 18:00 - 18:15 0.25 PERFOB~ P 18:15 - 19:45 1.50 PERFO P 19:45 - 20:15 0.50 PERFO P 20:15 - 00:00 3.75 PERFO P 10/28/2005 00:00 - 01:15 1.25 PERFO P 1 01:15 - 02:40 1.42 EVAL P Start: 10/18/2005 Rig Release: 10!28/2005 Rig Number: N1 Page 10 of 12 Spud Date: 5/6/1991 End: 10/28/2005 ', Phase ' Description of Operations LOWERI Circ CT for 15mins. Shut-in both master & swab valves & retest the BOP stack & tree as follows: Time WHP CTP IAP OAP Onset 11 0 975 0 0 3164 0 975 0 10 3164 0 966 0 20 3164 0 966 0 Observe leak on the coflex hose on the kill line -will replace & retest lap before pert job. LOWERI Stab injector on well & retest the wellbore via the CT as follows: Time WHP CTP IAP OAP Onset 26 0 950 0 0 3270 3130 1160 0 30 3204 2985 1155 0 LOWERI Changeout leaking coflex hose on the kill line. Unstab & S/B injector. P/test kill line to 250/4000psi - OK. LOW ER1 Line up & retest the wellbore via the kill line as follows: Time WHP CTP IAP OAP Onset 11 0 908 0 0 3109 0 1107 0 10 3069 0 1105 0 20 3047 0 1099 0 30 3040 0 1096 0 _> Passed: Leaked 2.2% of test pressure in 30 mins. Will not set LTP. LOWERI PJSM on perforation job. LOWERI R/U safety jt & prep to M/U perf guns. LOWERI M/U 29jts of 2" HSD 6spf 2006PJ guns & blanks with CBF firing system. LOWERI M/U lower diconnect, 23 doubles of 1-1/4" CSH tbg & upper MHA. M!U injector. LOWERI RIH with perforating BHA#8 circ @ min rate. Tag PBTD @ 11572'. Pull to P/U wt & correct CTD to 11561.09' (PBTD as per CTD tally). PUH to ball drop postion @ 11543'. Meanwhile R/U sonogram detector to choke manifold for shot detection. LOWERI Load & launch 5/8" AL ball. R61H to 11531.2'. Chase ball @ 1.85bpm/2175psi. Slow to 0.80bpm/850psi @ 40bbls. Ball on seat after 53.4bbls away. S/D pumps & RBIH to 11535'. PUH very slowly & ramp up to 3000psi with btm shot @ 11530'. Observe guns fire with good pressure drop indication & sonogram detection. Perforated interval = 10925' - 11050', 11490' - 11530'. LOWERI Olpull 10k 2x. Continue POOH with pert gun BHA @ 45fpm pumping down the CT @ 1.5bpm/1300psi. POOH to 9640'. LOWERI S/D pump &flowcheck well for 15 mins ~ well stable. LOWERI POOH with pert gun BHA @ 48fpm pumping down the backside with +/-200psi WHP. LOWERI S/D pump &flowcheck well -- well stable. LOWERI POH w/ BHA, Std back 1 1/4" CSH, LD perf gun assy LOW ERi POH w! BHA, LD perf gun assy, all shots fired, load out guns and pert tools LOWERI Blow back air to coil, RU on IA, Pressure up to 1000 psi, RU on Printed: 10/31 /2005 11:40: t 8 AM c: BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: P-06 Common Well Name: P-06 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date, From - To Hours ask Code ~I ---' - 10/28/2005 101:15 - 02:40 ~ 1.42 ~ EVAL ~ P 02:40 - 04:30 04:30 - 06:15 1.831 EVAL I P 1.751 EVAL 1 P Spud Date: 5/6/1991 Start: 10/18/2005 End: 10/28/2005 Rig Release: 10/28!2005 Rig Number: N1 NPT ~, Phase it Description of Operations LOWERI kill line, establish injection rate w/ 140 deg 2 percent KCL water filtered to 5microns at 314 bpm w/ 1600 psi for 5 min, increase WHP to 2150 psi at .9 bpm for 5 min, increase WHP to 2585 psi at 1.4 bpm for 5 min, increase WHP to 2919 psi at 2.45 bpm, pressure started breaking back, shut down pumps had 2700 psi, shut in kill line had 1900 psi ISIP, pumped total of 53 bbls, monitor WHP for 15 min, pressure dropped to 0 psi in 13 minutes. IA at 1200 psi LOWERI Open kill line, establish injection rate at 3 bpm, 2800 psi, 63 bbls pumped, monitor IA at 1350 psi Time BPM WHP BBLS IA/OA PSI 02:55 3.0 2732 100 1390/260 03:10 B/D IA f/ 1430 psi to 1030/280 03:13 3.0 2574 150 1042/308 03:29 3.0 2629 200 1088/500 03:30 B/D OA f/ 504 psi to 1075/38 03:46 3.0 2525 250 1135/170 04:02 3.0 2512 300 1188/339 04:03 4.0 2717 306 1206/353 04:20 4.0 2692 375 1334/469 04:27 4.0 2677 400 1379/509 04:29 B/D OA f/ 509 psi to 1370/10 LOWERI Contin ue injecting 2% KCL filtered to 5microns as follows: Time BPM WHP BBLS IA/OA PSI 04:33 B/D IA f/ 1377 psi to 1027/6 04:38 4.0 2699 450 1064/31 04:51 4.0 2721 500 1143/95 05:04 4.0 2651 550 1206/150 05:17 4.0 2538 600 1261/199 05:29 4.0 2527 650 1302/237 05:42 4.0 2468 700 1338/271 05:54 4.0 2439 750 1354/300 05:55 B/D IA f/ 1354 psi to 1014/260 05:56 B!D OA f/ 260 psi to 1010/35 06:11 4.0 2428 800 1041/65 06:15 - 07:30 07:30 - 08:00 1.251 EVAL I P 0.501 WHSUR I P LOWERI Continue injecting 2% KCL filtered to 5microns as follows Time BPM WHP BBLS IA/OA PSI 06:15 3.96 2428 864 1075/104 06:27 ci.95 2435 904 1093/122 06:32 3.92 2424 922 1074/131 06:37 c1.95 2435 936 1064/132 06:40 4.04 2391 946 1040(128 06:48 4.08 2417 978 872/74 06:53 4.08 2410 1000 734/15 ..07:05 4,05 2417 1044 493/0 07:13 4.05 2406 1078 363/0 07:20 4.08 2406 1108 270/0 07:27 4.08 2406 1134 128/0 POST Line up & bullhead 48bbls of diesel to freeze-protect wellbore. SI tree valves. Printed: 10/31/2005 11:40:18 AM Printed: 10/31/2005 11:40:18 AM Halliburton Sperry-Sun North Slope Alaska BPXA P-066 Job No. AKMW4005436, Surveyed: 25 October, 2005 Survey Report 8 November, 2005 Your Ref: API 500292216602 Surface Coordinates: 5947233.00 N, 631246.00E (70° 15' 50.1810" N, 148° 56' 19.9445" IA/) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevafion: 92.10ft above Mean Sea Level 5ef'~rl~"-5~tJ1'1 ~~~-~ ~ ~ ~ ~~~ ~ ~~~v ~ c ~ Survey Ref.• svy4689 A HailObUrtan Company • Halliburton Sperry-Sun Survey Report for P-066 Your Ref: APl 500292216602 Job No. AKMW4005436, Surveyed: 25 October, 2005 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Dept h Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 9953. 45 43. 480 21 .360 8791. 36 8883. 46 2986.62 N 69.24 W 5950217.96 N 631124.71E 2962.60 Tie On Point MWD Magnetic 9971. 60 43. 180 21 .350 8804. 57 8896. 67 2998.22 N 64.71 W 5950229.64 N 631129.04E 1 .653 2973.38 9976. 00 43. 060 21 .350 8807. 78 8899. 88 3001.03 N 63.61 W 5950232.46 N 631130.08E 2. 727 2975.98 Window Point 9992. 84 44. 410 21 .350 8819. 94 8912. 04 3011.87 N 59.37 W 5950243.38 N 631134.13E 8. 017 2986.06 10020. 50 47. 050 21 .200 8839. 25 8931. 35 3030.32 N 52.19 W 5950261.95 N 631141.00E 9. 552 3003.21 10062. 27 52. 070 20 .910 8866. 34 8958. 44 3059.98 N 40.77 W 5950291.81 N 631151.89E 12. 030 3030.79 10092. 16 56. 040 20 .550 8883. 88 8975. 98 3082.61 N 32.21 W 5950314.58 N 631160.06E 13. 318 3051.86 10122. 09 60. 260 20 .200 8899. 67 8991. 77 3106.44 N 23.36 W 5950338.56 N 631168.49E 14. 134 3074.07 10154. 34 65. 370 16 .850 8914. 40 9006. 50 3133.63 N 14.27 W 5950365.91 N 631177.10E 18. 339 3099.57 10185. 03 69. 870 13 .330 8926. 09 9018. 19 3161.02 N 6.90 W 5950393.42 N 631184.00E 18. 094 3125.53 10215. 22 71. 430 10 .840 8936. 09 9028. 19 3188.87 N 0.94 W 5950421.37 N 631189.47E 9. 341 3152.16 10249. 39 75. 070 1 .880 8945. 95 9038. 05 3221.35 N 2.65E 5950453.91 N 631192.50E 27. 269 3183.71 10281. 22 78. 590 357 .470 8953. 21 9045. 31 3252.33 N 2.47E 5950484.88 N 631191.78E 17. 442 3214.36 10311. 73 80. 970 351 .130 8958. 63 9050. 73 3282.19 N 0.52 W 5950514.68 N 631188.27E 21. 886 3244.33 10343. 67 85. 370 353 .240 8962. 43 9054. 53 3313.60 N 4.83 W 5950546.01 N 631183.41E 15. 257 3276.03 10374. 98 88. 900 356 .940 8963. 99 9056. 09 3344.74 N 7.50 W 5950577.10 N 631180.20E 16. 321 3307.22 10408. 63 92. 510 2 .230 8963. 58 9055. 68 3378.37 N 7.74 W 5950610.72 N 631179.37E 19. 029 3340.50 10443. 25 94. 360 8 .220 8961. 50 9053. 60 3412.77 N 4.60 W 5950645.17 N 631181.91E 18. 078 3374.02 10481. 81 94. 790 16 .650 8958. 42 9050. 52 3450.27 N 3.67E 5950682.81 N 631189.52E 21. 821 3409.83 10512. 99 100. 180 14 .210 8954. 36 9046. 46 3480.06 N 11.89E 5950712.73 N 631197.23E 18. 947 3438.03 10539. 64 102. 470 15 .440 8949. 12 9041. 22 3505.32 N 18.58E 5950738.11 N 631203.47E 9. 712 3461.98 10573. 19 103. 080 7 .510 8941. 69 9033. 79 3537.35 N 25.08E 5950770.25 N 631209.42E 23. 122 3492.66 10604. 63 101. 590 3 .640 8934. 98 9027. 08 3567.91 N 28.06E 5950800.86 N 631211.87E 12. 925 3522.42 10632. 44 100. 620 358 .350 8929. 62 9021. 72 3595.19 N 28.54E 5950828.14 N 631211.86E 18. 988 3549.31 10664. 09 100. 880 349 .890 8923. 70 9015. 80 3626.09 N 25.35E 5950858.98 N 631208.14E 26. 273 3580.33 10702. 90 100. 090 345 .140 8916. 64 9008. 74 3663.34 N 17.10E 5950896.08 N 631199.24E 12. 205 3618.40 10731. 83 98. 500 341 .080 8911. 96 9004. 06 3690.65 N 8.81E 5950923.24 N 631190.47E 14. 900 3646.65 10760. 94 99. 820 334 .560 8907. 32 8999. 42 3717.25 N 2.03 W 5950949.65 N 631179.17E 22. 572 3674.59 10792. 17 95. 250 337 .330 8903. 23 8995. 33 3745.51 N 14.64 W 5950977.68 N 631166.07E 17. 071 3704.43 10824. 18 90. 220 338 .090 8901. 70 8993. 80 3775.08 N 26.76 W 5951007.04 N 631153.43E .15. 892 3735.51 10855. 56 89. 520 341 .080 8901. 77 8993. 87 3804.49 N 37.71 W 5951036.25 N 631141.98E 9. 786 3766.23 10887. 07 86. 170 345 .840 8902. 96 8995. 06 3834.66 N 46.67 W 5951066.26 N 631132.49E 18. 462 3797.41 10916. 34 82. 030 348 .130 8905. 97 8998. 07 3863.02 N 53.23 W 5951094.50 N 631125.44E 16. 143 3826.44 10953. 76 76. 120 347 .780 8913. 05 9005. 15 3898.94 N 60.89 W 5951130.28 N 631117.15E 15. 820 3863.10 10988. 98 77. 800 341 .960 8921. 01 9013. 11 3932.04 N 69.85 W 5951163.22 N 631107.62E 16. 789 3897.18 BPXA • 8 November, 2005 - 8:14 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for P-068 ' Your Ref: API 500292216602 Job No. AKMW4005436, Surveyed: 25 October, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 11027.06 79.740 335.970 8928.43 9020.53 3966.88 N 83.25 W 5951197.83 N 631093.61E 16.247 3933.65 11057.82 81.670 331.920 8933.40 9025.50 3994.14 N 96.59 W 5951224.85 N 631079.80E 14.429 3962.62 11085.34 84.140 329.980 8936.80 9028.90 4018.01 N 109.85 W 5951248.49 N 631066.13E 11.379 3988.22 11121.77 84.410 324.340 8940.44 9032.54 4048.46 N 129.50 W 5951278.58 N 631045.95E 15.422 4021.29 11151.61 84.490 320.820 8943.32 9035.42 4072.04 N 147.54 W 5951301.85 N 631027.50E 11.744 4047.34 11185.46 82.380 314.650 8947.20 9039.30 4096.91 N 170.14 W 5951326.33 N 631004.47E 19.150 4075.35 11221.77 85.730 312.540 8950.96 9043.06 4121.81 N 196.29 W 5951350.76 N 630977.89E 10.887 4103.93 11251.01 89.690 310.250 8952.13 9044.23 4141.13 N 218.21 W 5951369.69 N 630955.64E 15.641 4126.34 11282.49 92.690 307.070 8951.47 9043.57 4160.78 N 242.78 W 5951388.92 N 630930.73E 13.885 4149.49 11315.42 93.300 304.250 8949.75 9041.85 4179.95 N 269.49 W 5951407.62 N 630903.69E 8.750 4172.49 11345.78 94.890 305.840 8947.58 9039.68 4197.34 N 294.28 W 5951424.57 N 630878.60E 7.397 4193.44 11379.73 94.980 312.710 8944.66 9036.76 4218.74 N 320.45 W 5951445.51 N 630852.06E 20.162 4218.56 11415.00 94.630 319.580 8941.70 9033.80 4244.07 N 344.79 W 5951470.41 N 630827.29E 19.435 4247.28 11450.21 93.740 325.400 8939.13 9031.23 4271.91 N 366.16 W 5951497.88 N 630805.43E 16.678 4278.04 11487.24 94.360 328.920 8936.51 9028.61 4302.94 N 386.19 W 5951528.55 N 630784.87E 9.629 4311.75 11520.01 94.360 335.090 8934.02 9026.12 4331.78 N 401.52 W 5951557.12 N 630769.04E 18.774 4342.58 11554.38 90.750 334.210 8932.49 9024.59 4362.80 N 416.21 W 5951587.88 N 630753.80E 10.810 4375.47 11584.26 91.190 340.550 8931.98 9024.08 4390.36 N 427.70 W 5951615.24 N 630741.84E 21.266 4404.46 11614.34 91.280 340.030 8931.33 9023.43 4418.68 N 437.84 W 5951643.37 N 630731.20E 1.754 4433.98 11646.21 93.920 334.030 8929.89 9021.99 4447.97 N 450.26 W 5951672.45 N 630718.28E 20.549 4464.82 11677-.76 89.600 330.160 8928.92 9021.02 4475.83 N 465.01 W 5951700.04 N 630703.04E 18.378 4494.59 11710.43 85.730 326.990 8930.25 9022.35 4503.68 N 482.02 W 5951727.59 N 630685.54E 15.306 4524.70 11742.96 84.140 324.870 8933.12 9025.22 4530.51 N 500.17 W 5951754.11 N 630666.93E 8.126 4553.98 11771.73 81.410 319.940 8936.74 9028.84 4553.12 N 517.58 W 5951776.41 N 630649.13E 19.467 4578.96 • 11800.00 81.410 319.940 8940.96 9033.06 4574.52 N 535.57 W 5951797.49 N 630630.77E 0.000 4602.83 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 351.280° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11800.OOft., The Bottom Hole Displacement is 4605.76ft., in the Direction of 353.322° (True). 8 November, 2005 - 8:14 Page 3 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for P-066 Your Ref.• API 500292216602 Job No. AKMW4005436, Surveyed: 25 October, 2005 North Slope Alaska Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9953.45 8883.46 2986.62 N 69.24 W Tie On Point 9976.00 8899.88 3001.03 N 63.61 W Window Point 11800.00 9033.06 4574.52 N 535.57 W Projected Survey BPXA • Survey tool program for P-O6B From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 9953.45 8883.46 To Measured Vertical Depth Depth (ft) (ft) 9953.45 8883.46 11800.00 9033.06 Survey Tool Description BP High Accuracy Gyro - GCT-MS (P-06) MWD Magnetic (P-06B) • 8 November, 2005 - 8:14 Page 4 of 4 DrillQuest 3.03.06.008 TREE=: 4-1/16' GNV WELLHEAD = 5M FMC ACTUATOR = OTIS KB. ELEV = 77.90' BF. ELEV = 55.41' KOP = 9976' Max Angle = 103° @ 10573' Datum MD = ~~ 9964' Datum TVD = 8800' SS FROM DRLG -DRAFT 10-3/4' CSG, 45.5ti, NT-80, D = 9.950" TOPOF 3-1/2" X 3-3116" X 2-718" LNR EST TOP OF LNR CMT 3-1/2" XNIP, D = 2.813" 14-1/2' TBG, 12.61, 13-CR .0152 bpf, D = 3.958' I I 9647' I I 9666' I I 9675' I 4-1 /2' TBG, 12.61, 13-C R .0152 bpf , D = 3.958' 9742' NOTE: Tailpipe has backed off and is resting on the 5 1/2" liner top Minimum ID = 2.37" @ 10909' 2-7/8" STL LNR 17-5/8" CSG, 29.7i/, NT-95-HS, D = 6.875" I I MECHANICAL WHIPSTOCK I~ 9976' WINDOW 9976' - 9984' Top 2 7/8" Deployment Sleeve 10,002' PERFORATION SUMMARY REF LOG: MWD/EWR/SGRC/SROP OF 10/25/05 A NGLE AT TOP PERF: 81 @ 10925' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE 2" 6 10925 - 11050 O 10/27/05 2" 6 11490 - 11530 O 10/27/05 OF WHIPSTOCK 10040' RA TAG 10049' rOP OF CEMENT 10077 5-112" LNR, 174, 13-CR D=4.892" 2-7/8" LNR, 6.Sf, L80, .00579 bpf, D= 2.37' H 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 05/23/91 SJA ORIC3INAL COMPLETION 11103/OS DAV/TLH GLV CIO 12/25/97 PARKB2 CTD SIDETRACK (P-06A) 11!22/01 CH/TP CORRECTIONS 08/06/03 JLG/TLP ADPERFS 04/18/04 KS/KAK GLV Cl0 10/28105 JUE NORDIGI CTD SIDETRACK P ~O ~ ~ 4 1~ N P ~ 973R10' S MILLED TO 3 80 ID.' LNR. CTD Sidetrack WELL ANGLE> 70° ~ 10150' 8 > 90° ~ 10364'. ID ~'-~"~ OBSTRUCTION ~ 10550' CTM. MILLED TO 10568' I ' CTM W/2.25" ON 11A5/01. I ~ I 4-1 /2" OTIS SSSV NIP, ID = 3.813" C`"AS 1 IFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2985 2893 0 CAMCO DOME BK 16 11/03/05 4 5514 5389 25 CAMCO DOME BK 16 11 /03105 3 7729 7133 39 CA MCO DOME BK 16 11 /03/OS 2 9267 8297 43 CAMCO SO BK 22 11/03/05 1 9636 8565 44 CAMCO ""DMY BK 0 11103/OS "M A NDRt3 C OV @i®W !GEM EiY I 9664' 4-1 /2" PKR SWS Nom, D = 3.813' 9677' 7-518' X 4-1 /2" TNV HBBP PKR, ID = 4.00" 9699' 3-1 /2'x3-3116 XO, D = ???? 9709' 4-1/2" PKR SWS NIP, ID= 3.813" 9731' 4-1/2" FKR SWN NIP, MILLED TO 3.80' 9739' 7-5/8" X 5-112" TNV LNR HGR WffIFJ3ACK 9743' 4-1/2" WLEG, D= 3.958" 9732' ELMD TT LOG NOT AVA~.ABLE 1 3-3/16" X 2-7/8' CMT'D 8 PERFD I 11 LSL SUB, 3-31/16" X 2-7/8" XO ll Sg-7~ IBPw/ support ppe to TD 11597' 11800' CTD 5-112" LNR M0..LOUT WNDOW 10039' -10045' (OFF WH~STOCK) ~ PBTD -r 1- 2063' ~ PRUDHOE BAY UNIT WELL R~O66i PERMR No: 205-138 API No: 50-029-22166-02 SEC 31, T11 N, R13E, 2506' FSL 8 1963' FWL BP Exploration (Alaska} • ., 15-Nov-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well P-06B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey 9,953.45' MD Window /Kickoff Survey: 9,976.00' MD (if applicable) Projected Survey: 11,800.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 . / , , Date ~ 1 ~t /.~~ US Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~.~~'' f ~ ~~~~_'3 ~ ' ' ~ ! ~~"', ' '~ r ~°° ~ ~ ~~ ~ ~;, ~p FRANK H. MURKOWSKI, GOVERNOR ~~ ~, ~ .~ ~; as ,, 3 ~ ~ ~v d ~~ OI~ ~ V[t>•-7 ~ 333 W. T" AVENUE, SUITE 100 C01~5ERQA"!`IO1~T COli1~IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Ted Stagg Fax (so7) 27s-7sa2 CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU P-06B BP Exploration (Alaska) Inc. Permit No: 205-138 Surface Location: 2506' FSL, 1963' FWL, SEC. 31' T11N, R13E, UM Bottomhole Location: 2010' FSL, 1228' FWL, SEC. 30 T 11 N R 13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petro u field inspector at (907) 659- 3607 (pager) . K. DATED this~~'' day of month, 2005 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. ~- -(9.5~ '~'`lCl~ ~~t 2 ~ t~ ~ S- STATE OF ALASKA ALASKA C3i"L AND GAS CONSERVATION COM ISSION ~,`~_~ ~ ; PERMIT TO DRILL ~ ~~ 20 AAC 25.005 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ^ Development Oil ^ Multiple Zone ^ Stratigraphic Test ®Service ^ Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU P-06B 9~2~ os 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12100 ~ TVD 8970ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2506' FSL 1983' FWL SEC T11N R13E 31 UM 7. Property Designation: ADL 028288 . Pool , , . , , , Top of Productive Horizon: 295' FSL, 1925' FWL, SEC. 30, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spu Octobe 12, 05 Total Depth: 2010' FSL, 1228' FWL, SEC. 30, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 16,460' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 631246 - 5947233 Zone- ASP4 10. KB Elevation (Height above GL): 92.11 feet 15. Distance to Nearest well Within Pool 175' to P-06A 16. Deviated Wells: Kickoff Depth: 9970 -feet Maximum Hole Angle: 103 ~ de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3120 ~ Surface: 2240 1 Casing rogram: Size Specifications Setting Dep#h To Bottom Quantity of ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data a-va^ x 4-1/4" 33!16° x z-~/e° 6.2# / 6.16# L-80 STL 2450' 9650' 8571' 12100' 8970' 152 cu ft Class 'G' 19. PRESENT W ELL CONDIT ION SUMMARY (To be completed for. Redrill AND Re-entry Operations) Total Depth MD {ft): 12130 Total Depth TVD (ft}: 9120 Plugs (measured): None Effective Depth MD (ft): 12063 Effective Depth TVD (ft): 9090 Junk (measured): None Casing Length Size Cement Volume MO TVD tr trl n u t r 120' 20" 120' 120' 2687' 10-3/4" 2939 cu ft Permafrost 2687' 2687' 9967' 7-5/8" 1461 cu ft Class 'G' 9967' 8893' Pr i 300' 5-1/2" 165 cu ft Class 'G' 9739' - 10039' 8728' - 8947' Liner 2132' 2-718" 109 cu ft Class 'G' 9998' - 12130' 8916' - 9120' Perforation Depth MD (ft): 10425' - 11900' Perforation Depth TVD (ft): 9043' - 9054' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ^ Properry Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Stagg, 564-4694 Printed Name Ted Stagg Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 564-4694 Date ~ o. Terrie Hubble, 564-4628 Commission Us® Only Permit To Drill Number: .Z_.t1S~% ~ API Number: 50- 029-22166-02-00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Sampl required ^ Yes ,~ No Mud Log Required ^ Yes ~No ..{_. r~ Hy ogen ulfide Measures (Yes ^ No Directional Survey Required J$~Yes ^ No Other: ~~~ ~ l I" 0 S t3~' ~ S-~ : ~~ l ~ rt'Gct.~.-`~i' ~ a APPROVED BY A roved B THE COMMISSION Date 0 Form 10-401 R2Eised Ol~p6~C ~~/ ~~ ~~` ~ ~ Y + ~Syrbmit Ir~Duplicate BP Prudhoe Bay P-06B CTD Sidetrack CTD Sidetrack Summary Rig Work: 1. MIRU Nordic 1 and test BOPE to 250 psi low an SQO`psi high. 2. Mi113.8" window at 9974' MD (8806'ss). - - 3. Drill approx. 2,126 ft of 4.125" to 4.25" OH. 4. Run 3 3/16" x 2 7/8" solid liner le ~ TOL at 9650' MD (8571'ss). ~ 5. Cement liner with a minimum 27 is to place top of cement at 9650' MD (8571'ss). 6. Cleanout liner and test to 2000 7. Perforate liner per asset instructions (expect approx. 400 ft of perfs) 8. Freeze protect well, RDMO Mud Program: • Well kill: 8.5 p~'€;~e • Milling/drillin 8. ppg Flo Pro or biozan for milling, new Flo Pro for drilling. - Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. - • All Class I wastes will go to Pad 3 for disposal. Casing Program: • 3 3/16" x 2 7/8" fully cemented liner • A minimum of 27 bbls 15.8' ppg cement will be used for liner cementing. Casing/Liner Information 10 3/4", NT-80, 45.5#, Burst 5210psi; collapse 2480 psi ';~ 7 5/8", NT-95, 29.7 #, Burst 9380 psi, collapse 5120 psi ~' ~ 5.5", 13Cr, 17#, Burst 7740 psi ;collapse 6280 psi Well Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. ~°° The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 103 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 16,460 ft. • Distance to nearest well within pool - 175 ft. (P-06A) Logging • MWD directional and Gamma Ray/Resistivity will be run over all of the open hole section. Hazards • The maximum recorded H2S level on P Pad 3S 92 pm (P-04L1 on 8/27/2000). Most wells are in the 10-20 ppm range.: '~- • Lost circulation risk is low. Reservoir Pressure ~ • Res. press. is estimated to be 3120 psi at 8800'ss (6.8 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2240 psi. ' TREE= 4-1/16" CIJV WELLHEAD= 5M FMC ACTUATOR= OTIS KB. ELEV = 77.90' BF. B_EV = 55.41' KOP= 4900' Max Angle = 103 @ 10553' Datum MD = 9964' DatumND= 8800' SS 10-3/4" CSG, 45.5#, NT-80, ID = 9.950" ~ 2687' Minimum ID = 2.37" @ 9998' TOP OF 2-7/8" LINER 41/2" TBG, 12.6#, 13-CR, .0152 bpf, ID= 3.958" H 9675' 4102" TBG, 12.6#,13-C R, .0152 bpf, ID= 3.958" 9742' 7-5/S" CSG, 29.7#, NT-95-HS, ID = 6.875" 9966' TOPOF2-7/8"LNR ID=2.37" 9998' PERFORATION SUMMARY REF LOG: SPERRY SUN GRIROPON 12/15/97 A NGLE AT TOP PERF: 92 @ 10425' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE 2" 6 10425 - 10475 O 08/06/03 2" 6 10499 - 10549 O 08/06(03 1-11/16" 4 10950 - 10990 O 12/25/97 1-11!16" 4 11010 - 11050 O 12/25/97 1-11/16" 4 11369- 11440 O 12/25/97 1-11116" 4 11460- 11480 O 12/25/97 1-11/16" 4 11812- 11900 O 12/25/97 P OF W HIPSTOCK RA TAG TOP OF CEMENT 5-1 /2"LNR, 17#, 13-C R, ID = 4.892" 10040' 10049' 10072' 2-7/8"LNR, 6.5#, L80, .00579 bpf, ID= 2.37" H 12130' PBTD I DOTE REV BY COMMENTS DATE REV BY COMMENTS 05123!91 SJA ORIGINAL COM PLETION 12/25/97 PARFO=R CTD SIDETRACK P-06A 11/22!01 CH/TP CORRECTIONS 08106/03 JLG/lLP ADPERFS 04/18/04 KS/KAK GLV GO PRUDHOEBAY UNIT WELL: P-06A PERMIT No: 197-2240 API No: 50-029-22166-01 SEC 31, T11 N, R13E, 2506' FSL & 1963' FWL BP Exploration (Alaska) P-0 ~~ SAFETY NOTES: CHROME4-1@" TBG~ 5-1/2" LNR. 4-1/2" XN NIP @ 9731' IS MILLED TO 3.80" ID. W ELL ANGLE > 70° @ 10150' 8 > 90° @ 10364'. ID OBSTRUCTION @ 10550' CTM. M~L® TO 10568' CTM W/ 2.25" ON 11105/01. 2103' 41/2" OTIS SSSV NIP, ID= 3.813" GAS LIFT MANDRELS ST MD N D DEV TYPE V LV LATCH RDRT DATE 5 2985 2893 0 CAMCO DMY BK 0 04!18!04 4 5514 5389 25 CAMCO DMY BK 0 04/18/04 3 7729 7133 39 CAMCO DMY BK 0 04/18/04 2 9267 8297 43 CAMCO DMY BK 0 1 9636 8565 44 CAMCO DMY BK 0 04/18/04 9664' 41/2" RCR SWS NIP, D = 3.813" 9677' 7-5/8" X 4-1/2" TIW HBBP PKR, ID = 4.00" 9709' 9731' 41/2" PKRSWS NIP, D =3.813" 41/2" R<R SWN NIP, MILLED TO 3.80" 9739' 7-5/8" X 5-1/2" TM/ LNR HGR W/TIEBACK 9743' 9732' 4-112" WLEG, D = 3.958" ELMD TT LOG NOTAVAILABLE 81/2" LNRMILLOUT WINDOW 10039'-10045 (OFF WHIPSTOCK) l`REE _ 4-1/16" CMJ WELLHEAD = 5M FMC ACTUATOR = KB. ELEV = OTIS 77.90' BF. ELEV = 55.41' KOP = 4900' Max Angle = 103 @ 10553' Datum MD = gggq~ Datum TVD = 8800' SS 10-3/4" CSG, 45.5#, NT-80, 10 = 9.950" P-06B Proposed CTD Sidetrack I ~ I ITOPOF 3-3/16" LNf~ 9650' Top of Cement 9650' 3.5" X Nip 2.813" ID 9660' 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 9675' 4-1/2" TBG, 12.6#, 13-CR .0152 bpf, ID = 3.958" 9742' NOTE: Tailpipe has backed off and is resting on the 5 1/2" liner top CSG, 29.7#, NT-95-HS, ID = 6.875" 9966' Top 2 7/8" Deployment Sleeve 10,002' PERFORATgN SUMMARY REF LOG: SPERRY SUN GR/ROP ON 12/15/97 ANGLE AT TOP PERF: 92 @ 10425' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2" 6 10425 - 10475 isolated proposed 2" 6 10499 - 10549 isolated proposed 1-11/16" 4 10950 - 10990 isolated proposed 1-11/16" 4 11010 - 11050 isolated proposed 1-11/16" 4 11369 - 11440 isolated proposed 1-11/16" 4 11460 - 11480 isolated proposed 1-11/16" 4 11812 - 11900 isolated proposed I i yr Ur vv rnra 1 UI:K I-1 10040 RA TAG 10049' TOP OF CEMENT 10072' 5-1 /2" LNR 17#, 13-C R, ID = 4.892" -~ 1(1d7A' t-1/2" OTIS SSSV NIP, ID = 3.813" ne c ~ IR AAA ~.ll11"fn n ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2985 2893 0 CAMCO DMY BK 0 04/18/04 4 5514 5389 25 CAMCO DMY BK 0 04/18/04 3 7729 7133 39 CAMCO DMY BK 0 04/18/04 2 9267 8297 43 CAMCO DMY BK 0 1 9636 8565 44 CAMCO DMY BK 0 04/18/04 ~ ybti4' I- -14-1/2" PKR SWS NIP, ID = 3.813 9677' 7-5/8" X 4-1/2" TMJ HBBP PKR ID = 4 00" , . 9709' 4-1/2" PKR SWS NIP, ID = 3.813" 9731' 4-1/2" PKR SWN NIP, MILLED TO 3.80" 9739' 7-5/8" X 5-1/2" TNV LNR HGR W/TIEBACK 9743' 4-1/2" WLEG, ID = 3.958" 1 9732' ELMD TT LOG NOT AVAILABLE 9974' --~ Mechanical Whipstock 10900' 3 3/16" x 2 7/8" 3-3/16" x 2 718" cmt'ed and perfed 12100' ~ 5-1/2" LNR MILLOUT WINDOW 10039' -10045' (OFF WHIPSTOCK) PBTD 1--I- 20-R~' ~ PRUDHOE BAY UNrr WELL: P-O6A P62Mrr No: 197-2240 API No: 50-029-22166-01 SEC 31, T11N, R13E, 2506' FSL 8 1963' FWL BP 6cploration (Alaska) 12-7/8" LNR, 6.5#, L80, .00579 bpf, ID = 2.37" 1 12130' • • __ _ EEOERO T qv nehs to True North Pten-. Poen a fP-oemlena. Pme) B P Amoco ~/~~ - P 08 m om M Meg tit North: 24.64° c~e.r.a ey fiMl Mltliaelwn Daly Mt rrzaos e{~~~! .` v.os IP-oa~l Pao M M alit Field B ~YY~ii ~~KJ - Plv~t. Plel1 gg nii. ~.l l..,~.~i. .~~ ~~ Strang 57586nT ~m ltn: nn~h~aen~,n ~~ `,L„ / Dp MgIe: 60.63' unecl i?u;-~Uiax;ia rr.er ~. \ Y Ddle: Bl16Y1006 cell IW1r1 :+U1 /'ISrU Model: bggrn2005 t.c~a~l hnr~ey~naslso~ml«rt t.w,~ r ...e.,ew .... 46ar-_ --- ------------._.. __.. REFERENCE INFORI.NTION - - ~5' _ 4~0o r i':: LoadnNe(WEI Rerwn~ce N Ce m. P~OB True Nnin _ ::. (TVA Mm~sea teya~ a P_U6B syM1 ~ ~ SenIm NS Rerere ts9t mOO 4600 - - 4 Maaz~ ~ [MpM Re ererea. 508 1 ~N 0 OOF Ca alemn McMOE. m Curvature B7 10 . L { +' ' r ~t] 1 ! 1 W ..,. d500 .... .___.. .. __. ...... ._. ... .. .._ • ~, Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~^ ~~ [NTE(7 Company: BP Amoco Date: 8/17/2005 Time:` 11:09:15 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeII: P-O6, True North .Site: PB P Pad Vertical(TVD) Reference: 10:06 5!611:991 00:00 92.1 Well: P-06 Section (VS) Reference: Well (O.OON,O.OOE,351. 28Azi) Wellpat6: PIan3, P-06B Survey CalculatioaMethod: Minimum Curvature Db: QraGe Field: Prudhoe Bay North Sbpe UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zoae: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB P Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5949377 .17 ft Latitude: 70 16 12.612 N From: Map Easting: 623154 .06 ft Longitude: 149 0 14.402 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.94 deg Well: P-06 Slot Name: O6 P-06 Well Position: +N/-S -2276.58 ft Northing: 5947232 .91 ft Latitude: 70 15 50.180 N +E/-W 8056.94 ft Easting : 631246 .51 ft Longitude: 148 56 19.930 W Position Uncertainty: 0.00 ft Wellpath: PIan3, P-066 Drilled From: P-06 Tie-on Depth: 9953.45 ft Current Datum: 10:06 5/6/1991 00: 00 Height 92 .10 ft Above System Datum: Mean Sea Level Magnetic Data: 8/16/2005 Declination: 24.64 deg Field Strength: 57586 nT Mag Dip Angle: 80.83 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 38.10 0.00 0.00 351.28 Plan: Plan #3 Date Composed: 8/16/2005 Version: 6 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <-- Latitude --> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easdag beg.Min Sec Deg Min See Dip. Dir. ft ft ft ft. ft P-06B Polygon 92.10 3270.12 -129.52 5950500.01 631060.02 70 16 22.342 N 148 56 23.701 W -Polygon 1 92.10 3270.12 -129.52 5950500.01 631060.02 70 16 22.342 N 148 56 23.701 W -Polygon 2 92.10 3886.47 -198.79 5951115.01 630980.02 70 16 28.403 N 148 56 25.718 W -Polygon 3 92.10 4803.52 -877.96 5952020.01 630285.02 70 16 37.422 N 148 56 45.496 W -Polygon 4 92.10 4869.25 -631.76 5952090.01 630530.02 70 16 38.069 N 148 56 38.327 W -Polygon 5 92.10 3961.32 97.58 5951195.01 631275.02 70 16 29.140 N 148 56 17.088 W -Polygon 6 92.10 3344.71 181.86 5950580.01 631370.02 70 16 23.075 N 148 56 14.635 W P-066 Fault 1 92.10 363321 -187.20 5950862.01 630996.02 70 16 25.913 N 148 56 25.380 W -Polygon 1 92.10 3633.21 -187.20 5950862.01 630996.02 70 16 25.913 N 148 56 25.380 W -Polygon 2 92.10 3671.11 679.66 5950915.01 631862.02 70 16 26.285 N 148 56 0.141 W P-068 Fault 2 92.10 4114.61 -547.89 5951337.01 630627.02 70 16 30.647 N 148 56 35.883 W -Polygon 1 92.10 4114.61 -547.89 5951337.01 630627.02 70 16 30.647 N 148 56 35.883 W -Polygon 2 92.10 4591.74 -32.45 5951823.01 631134.02 70 16 35.340 N 148 56 20.875 W P-066 Target 2 8992.10 3768.17 -10.80 5951000.01 631170.02 70 16 27.240 N 148 56 20.244 W P-066 Target 4 9012.10 4502.10 -513.13 5951725.01 630655.03 70 16 34.458 N 148 56 34.872 W P-O66 Target 3 9057.10 4171.71 -208.81 5951400.01 630965.02 70 16 31.209 N 148 56 26.010 W P-06B Target 1 9062.10 3382.41 27.48 5950615.01 631215.02 70 16 23.446 N 148 56 19.130 W P-06B Targei 5 9062.10 4791.26 -748.14 5952010.02 630415.03 70 16 37.302 N 148 56 41.716 W • Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~ LNTE(~ Company: BP Amoco Date: 8/17!2005 Time: 11:09:15 Page: 2 Field: Prudhoe Bay Ca-ordinate(NE) Reference: Well: P-06, True North ~ Site: PB P Pad Vertical (TVD)'Reference: 1 0:06 516!1991 00:00 92.1 f Well: P-06 Section (VS) Reference: Well (O.OON,O.OOE,351.28Azi) Wellpath: PIan3, P-O66 Survey Calculation Method: Minimum Curvature Db: O racle Annotation MD TVD ft ft: 9953.45 8883.46 TIP 9970.00 8895.50 KOP 9990.00 8909.86 End of 9°/100' DLS 10020.00 8930.27 4 10270.00 9044.00 5 10428.68 9062.33 6 10514.28 9053.54 7 10650.00 9024.77 Fault 1 10764.28 9000.48 8 10849.28 8991.65 9 10974.28 9010.53 10 11274.28 9056.82 11 11445.00 9045.92 Fault 2 11549.26 9030.12 12 11749.28 9012.19 13 11899.28 9026.17 14 12100.00 9062.30 TD Plan Section Information MD Inch Azim TVD +N!-S +E/_W DLS Build Turn TFO Target - -~ ft deg deg ft ft - ` ft deg/100ft deg/100ft deg/100Ft -deg 9953.45 43.48 21.36 8883.46 2986.61 -69.20 0.00 0.00 0.00 0.00 9970.00 43.21 21.35 8895.50 2997.19 -65.06 1.63 -1.63 -0.06 181.45 9990.00 45.01 21.35 8909.86 3010.15 -60.00 9.00 9.00 0.00 0.00 10020.00 49.21 21.35 8930.27 3030.62 -52.00 14.00 14.00 0.00 0.00 10270.00 76.82 356.73 9044.00 3247.04 -23.59 14.00 11.04 -9.85 315.00 10428.68 90.00 14.77 9062.33 3402.84 -7.56 14.00 8.31 11.37 55.00 10514.28 101.80 16.89 9053.54 3484.62 15.61 14.00 13.78 2.47 10.00 10764.28 101.93 341.10 9000.48 3724.92 11.40 14.00 0.05 -14.32 274.00 10849.28 90.03 341.10 8991.65 3804.76 -15.94 14.00 -14.00 0.00 180.00 10974.28 72.53 341.10 9010.53 3921.19 -55.82 14.00 -14.00 0.00 180.00 11274.28 90.32 302.44 9056.82 4147.22 -236.96 14.00 5.93 -12.89 291.00 11549.28 100.44 339.80 9030.12 4355.79 -406.10 14.00 3.68 13.59 73.50 11749.28 89.69 313.81 9012.19 4520.60 -514.38 14.00 -5.38 -13.00 249.00 11899.28 79.70 332.38 9026.17 4639.24 -603.71 14.00 -6.66 12.38 119.00 12100.00 79.98 303.83 9062.31 4784.68 -734.21 14.00 0.14 -14.23 268.00 Survey MD dncl Azim SS TVD N/S E/W MapN MapE bL5 VS TFO Toa ft deg deg ft ft ft ft ft deg/100ft ' ft deg 9953.45 43.48 21.36 8791.36 2986.61 -69.20 5950217.61 631125.26 0.00 2962.55 0.00 M W D .- 9970.00 43.21 21.35 8803.40 2997.19 -65.06 5950228.26 631129.22 1.63 2972.38 181.45 MWD 9975.00 43.66 21.35 8807.03 3000.39 -63.81 5950231.49 631130.41 9.00 2975.35 0.00 MWD 9990.00 45.01 21.35 8817.76 3010.15 -60.00 5950241.31 631134.06 9.00 2984.43 360.00 MWD 10000.00 46.41 21.35 8824.74 3016.82 -57.39 5950248.02 631136.55 14.00 2990.62 0.00 M W D 10020.00 49.21 21.35 8838.17 3030.62 -52.00 5950261.92 631141.70 14.00 3003.44 0.00 MWD 10025.00 49.71 20.70 8841.42 3034.17 -50.63 5950265.49 631143.00 14.00 3006.74 315.00 MWD 10050.00 52.24 17.59 8857.16 3052.51 X4.27 5950283.94 631149.04 14.00 3023.91 315.42 MWD 10075.00 54.85 14.70 8872.02 3071.82 -38.69 5950303.34 631154.28 14.00 3042.15 317.38 MWD 10100.00 57.53 11.98 8885.93 3092.03 -33.91 5950323.63 631158.71 14.00 3061.40 319.10 MWD 10125.00 60.26. 9.42 8898.84 3113.06 -29.94 5950344.72 631162.31 14.00 3081.59 320.61 MWD 10127.34 60.52 9.19 8900.00 3115.07 -29.61 5950346.74 631162.61 14.00 3083.52 321.93 P-066 T 10150.00 63.04 7.00 8910.72 3134.83 -26.80 5950366.55 631165.07 14.00 3102.63 322.05 MWD 10171.36 65.44 5.03 8920.00 3153.97 -24.79 5950385.71 631166.75 14.00 3121.24 323.08 P-06B T 10175.00 65.86 4.70 8921.50 3157.27 -24.51 5950389.01 631166.97 14.00 3124.46 323.94 MWD 10200.00 68.71 2.50 8931.16 3180.28 -23.07 5950412.04 631168.01 14.00 3146.98 324.08 MWD 10225.00 71.58 0.38 8939.65 3203.78 -22.48 5950435.55 631168.19 14.00 3170.12 324.93 MWD 10250.00 74.48 358.33 8946.94 3227.69 -22.75 5950459.45 631167.50 14.00 3193.80 325.65 MWD 10270.00 76.82 356.73 8951.90 3247.04 -23.59 5950478.78 631166.33 14.00 3213.05 326.25 MWD • ~, Baker Hughes INTEQ Baker Hughes INTEQ Planning Report LNTEQ Company:- BP Amoco Date:. 'tl/17/2005 Time: " 11;09:15 Page: 3 'Field: Prudhoe_Bay Co-ordinate(NE) Reference: Well: P-06, True Notih Site: PB P Pad Vergcal (TVD) Reference: 1 0:06 516/1991: 00:00 92.1 Well: P-O6 Section (VS) Reference; Well (O.OON,O.OpE,351.28Azi) Welipathc PIan3, P-066 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Intl Azim 'SS TVD N/S E/W MapN MapE DLS > VS TFO Tool j ft deg deg ' ft ft ft ft ft deg/100ft ft deg 10275.00 77.22 357.32 8953.02 3251.91 -23.54 5950483.64 631165.99 14.00 3217.90 55.00 M W D 10300.00 79.25 0.23 8958.12 3276.37 -24.36 5950508.09 631165.04 14.00 3242.16 54.87 MWD 10325.00 81.30 3.11 8962.35 3301.00 -23.64 5950532.73 631165.33 14.00 3266.39 54.27 MWD 10350.00 83.38 5.95 8965.68 3325.70 -21.68 5950557.45 631166.86 14.00 3290.51 53.79 MWD 10375.00 85.47 8.77 8968.11 3350.37 -18.50 5950582.17 631169.62 14.00 3314.41 53.41 MWD 10400.00 87.58 11.57 8969.62 3374.93 -14.09 5950606.80 631173.59 14.00 3338.02 53.14 MWD 10425.00 89.69 14.36 8970.22 3399.28 -8.48 5950631.25 631178.77 14.00 3361.24 52.97 MWD 10428.68 90.00 14.77 8970.23 3402.84 -7.56 5950634.82 631179.64 14.00 3364.62 52.90 MWD 10450.00 92.94 15.29 8969.68 3423.42 -2.03 5950655.50 631184.80 14.00 3384.12 10.00 MWD 10475.00 96.39 15.90 8967.65 3447.42 4.67 5950679.60 631191.08 14.00 3406.82 10.01 MWD 10500.00 99.83 16.53 8964.12 3471.18 11.58 5950703.48 631197.58 14.00 3429.26 10.06 MWD 10514.28 101.80 16.89 8961.44 3484.62 15.61 5950716.99 631201.38 14.00 3441.93 10.15 MWD 10525.00 101.90 15.36 8959.24 3494.69 18.52 5950727.11 631204.11 14.00 3451.45 274.00 MWD 10550.00 102.10 11.78 8954.04 3518.46 24.26 5950750.97 631209.43 14.00 3474.07 273.69 MWD 10575.00 102.26 8.21 8948.76 3542.52 28.50 5950775.10 631213.25 14.00 3497.21 272.94 MWD 10600.00 102.37 4.63 8943.43 3566.79 31.23 5950799.41 631215.56 14.00 3520.78 272.19 MWD 10625.00 102.43 1.04 8938.06 3591.17 32.44 5950823.81 631216.34 14.00 3544.70 271.42 MWD 10650.00 102.45 357.46 8932.67 3615.58 32.12 5950848.20 631215.60 14.00 3568.87 270.65 MWD 10675.00 102.42 353.87 8927.29 3639.92 30.27 5950872.50 631213.33 14.00 3593.21 269.88 MWD 10700.00 102.34 350.29 8921.92 3664.10 26.91 5950896.62 631209.54 14.00 3617.62 269.11 MWD 10725.00 102.22 346.71 8916.61 3688.03 22.04 5950920.47 631204.26 14.00 3642.02 268.34 MWD 10750.00 102.05 343.14 8911.35 3711.63 15.69 5950943.95 631197.49 14.00 3666.31 267.58 MWD 10764.28 101.93 341.10 8908.38 3724.92 11.40 5950957.16 631192.97 14.00 3680.10 266.83 MWD 10775.00 100.43 341.10 8906.31 3734.87 7.99 5950967.05 631189.39 14.00 3690.45 180.00 MWD 10800.00 96.93 341.10 8902.54 3758.25 -0.02 5950990.28 631180.98 14.00 3714.77 180.00 MWD 10825.00 93.43 341.10 8900.28 3781.80 -8.08 5951013.69 631172.51 14.00 3739.27 180.00 MWD 10850.00 89.93 341.10 8899.55 3805.44 -16.18 5951037.18 631164.00 14.00 3763.86 180.00 MWD 10875.00 86.43 341.10 8900.34 3829.07 -24.27 5951060.67 631155.50 14.00 3788.45 180.00 MWD 10900.00 82.93 341.10 8902.66 3852.62 -32.33 5951084.07 631147.03 14.00 3812.95 180.00 MWD 10925.00 79.43 341.10 8906.49 3875.99 ~i0.34 5951107.29 631138.62 14.00 3837.26 180.00 MWD 10950.00 75.93 341.10 8911.83 3899.09 -48.25 5951130.25 631130.31 14.00 3861.30 180.00 MWD 10975.00 72.56 341.00 8918.64 3921.84 -56.04 5951152.86 631122.12 13.46 3884.97 181.59 MWD 11000.00 73.85 337.60 8925.87 3944.22 -64.50 5951175.09 631113.27 14.00 3908.37 291.03 MWD 11025.00 75.19 334.24 8932.54 3966.21 -74.33 5951196.90 631103.06 14.00 3931.60 292.01 MWD 11050.00 76.57 330.93 8938.65 3987.73 -85.50 5951218.22 631091.52 14.00 3954.56 292.91 MWD 11075.00 78.00 327.65 8944.15 4008.69 -97.95 5951238.96 631078.70 14.00 3977.17 293.72 MWD 11100.00 79.47 324.41 8949.04 4029.02 -111.65 5951259.05 631064.65 14.00 3999.34 294.44 MWD 11125.00 80.96 321.20 8953.28 4048.64 -126.54 5951278.40 631049.42 14.00 4021.00 295.07 MWD 11150.00 82.49 318.02 8956.88 4067.48 -142.57 5951296.96 631033.07 14.00 4042.05 295.62 MWD 11175.00 84.04 314.86 8959.82 4085.47 -159.68 5951314.64 631015.65 14.00 4062.42 296.08 MWD 11200.00 85.61 311.71 8962.07 4102.54 -177.80 5951331.39 630997.24 14.00 4082.04 296.45 MWD 11225.00 87.19 308.58 8963.64 4118.62 -196.87 5951347.14 630977.89 14.00 4100.83 296.73 MWD 11250.00 88.77 305.46 8964.52 4133.66 -216.81 5951361.83 630957.69 14.00 4118.72 296.93 MWD 11275.00 90.35 302.53 8964.71 4147.61 -237.56 5951375.41 630936.71 13.31 4135.65 298.23 MWD 11300.00 91.34 305.89 8964.34 4161.66 -258.23 5951389.10 630915.80 14.00 4152.68 73.50 MWD 11325.00 92.33 309.25 8963.54 4176.89 -278.03 5951403.98 630895.73 14.00 4170.74 73.55 MWD 11350.00 93.31 312.61 8962.31 4193.25 -296.89 5951420.00 630876.59 14.00 4189.76 73.66 MWD 11375.00 94.28 315.98 8960.66 4210.67 -314.74 5951437.11 630858.44 14.00 4209.69 73.82 MWD 11400.00 95.23 319.36 8958.58 4229.08 -331.52 5951455.23 630841.35 14.00 4230.44 74.05 MWD 11425.00 96.17 322.75 8956.10 4248.43 -347.15 5951474.29 630825.38 14.00 4251.93 74.33 MWD 11450.00 97.08 326.15 8953.21 4268.63 -361.59 5951494.24 630810.60 14.00 4274.08 74.66 MWD 11475.00 97.97 329.57 8949.93 4289.61 -374.77 5951514.99 630797.05 14.00. 4296.82 75.06 MWD • ~, Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ^ c~vr~r1 Company: BP AmOCO Dater 8/17/2005. Time: 11:09115 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeIL•.P-06, True North Site: PB P Pad Vertical (TVD) Reference: 1 0:06..516/1991 00:00 92.1 Well: P-06 Section (VS) Reference: WeII (O.OON,O.OOE,351.28Azi) Wellpatb: PIan3, P-066 Snrvey Calculation Method: Minimum Curvature Db: O racle Survey MD Iucl Azim + SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft` ft ft ft deg/100ft ft deg 11500.00 98.84 333.00 8946.28 4311.29 -386.65 5951536.46 630784.79 14.00 4320.06 75.50 MWD 11525.00 99.67 336.44 8942.26 4333.60 -397.19 5951558.58 630773.87 14.00 4343.71 76.01 M W D 11550.00 100.40 339.71 8937.89 4356.45 -406.34 5951581.26 630764.32 13.20 4367.68 76.81 MWD 11575.00 99.13 336.40 8933.65 4379.30 -415.55 5951603.94 630754.72 14.00 4391.66 248.98 MWD 11600.00 97.83 333.11 8929.96 4401.66 -426.10 5951626.11 630743.79 14.00 4415.36 248.42 MWD 11625.00 96.50 329.85 8926.84 4423.45 -437.94 5951647.69 630731.57 14.00 4438.69 247.94 MWD 11650.00 95.16 326.60 8924.30 4444.59 -451.03 5951668.60 630718.11 14.00 4461.58 247.53 MWD 11675.00 93.79 323.37 8922.35 4465.00 -465.33 5951688.76 630703.46 14.00 4483.92 247.20 MWD 11700.00 92.42 320.15 8921.00 4484.60 -480.78 5951708.08 630687.67 14.00 4505.64 246.95 MWD 11725.00 91.03 316.93 8920.24 4503.32 -497.32 5951726.52 630670.80 14.00 4526.65 246.77 MWD 11750.00 89.64 313.90 8920.09 4521.10 -514.90 5951743.98 630652.92 13.36 4546.89 245.31 MWD 11775.00 87.94 316.96 8920.62 4538.90 -532.44 5951761.47 630635.08 14.00 4567.14 119.00 MWD 11800.00 86.25 320.03 8921.89 4557.59 -548.98 5951779.87 630618.21 14.00 4588.13 118.93 MWD 11825.00 84.57 323.11 8923.89 4577.11 -564.47 5951799.12 630602.39 14.00 4609.77 118.78 MWD 11850.00 82.91 326.21 8926.61 4597.38 -578.84 5951819.13 630587.66 14.00 4631.99 118.53 MWD 11875.00 81.27 329.33 8930.06 4618.32 -592.05 5951839.84 630574.10 14.00 4654.69 118.19 MWD 11900.00 79.69 332.28 8934.20 4639.86 -604.04 5951861.16 630561.73 13.25 4677.80 118.61 MWD 11925.00 79.59 328.73 8938.70 4661.26 -616.14 5951882.34 630549.26 14.00 4700.79 268.02 MWD 11950.00 79.53 325.17 8943.23 4681.86 X29.55 5951902.71 630535.49 14.00 4723.18 268.66 MWD 11975.00 79.51 321.61 8947.78 4701.59 -644.21 5951922.18 630520.49 14.00 4744.91 269.30 MWD 12000.00 79.52 318.05 8952.33 4720.38 -660.06 5951940.68 630504.32 14.00 4765.88 269.95 MWD 12025.00 79.58 314.49 8956.86 4738.14 -677.06 5951958.14 630487.02 14.00 4786.01 270.60 M W D 12050.00 79.68 310.93 8961.36 4754.82 -695.12 5951974.50 630468.67 14.00 4805.24 271.24 MWD 12075.00 79.81 307.38 8965.82 4770.35 -714.20 5951989.70 630449.33 14.00 4823.48 271.88 MWD . 12100.00 79.98 303.83 8970.20 ' 4784.67 -734.20 5952003.67 630429.07 14.00 4840.68 272.52 MWD • • are i ~_ of bag BAG of bag of slips Blind/Shears TOTs pipes 2 3/8" combi ram/slips ~ ~ Mud Cross I I Mud Cross of flow cross of blind/shears variable bore pipe 3 1/2"-2 7/8" TOTs of pipe/slips 2 3/8" combi ram/slips Flow Tee n Subject: P-OGA SCMT log From: "Stagg, Ted O (ORBIS)" <StaggTO@BP.com> Date: Wed, 21 Sep 2005 13:19:01 -0800 To: steve_davies@admin.state.ak.us, winton_aubert@admin.state.ak.us CC: "Montague, W Stuart" <MontagWS@BP.com>, "Hubble, Terrie L" <HubbleTL@BP.com> Steve and Winton, P-06B will be a water/MI injector that may now be pre-produced for a few months. Stuart Montague will contact you regarding the tentative plans to pre-produce the sidetrack. I have confirmed that there are no wells within 1/4 mile of the point at which P-06B wiH enter Zone 4. I should have addressed the potential need for a cement quality log when I applied for a Permit to Drill for P-06B, but I failed to do so. We did run an SCMT log on P-06A on July 29, 2005 in preparation for this sidetrack. The log shows excellent cement around the parent well 5 1!2" liner above the top of the P-06A 2 7/8" liner. P-066 will kick off in the Shublik, just a few feet above the top of the P-06A liner. The log clearly shows very good cement above the planned KOP at 9974' MD. This should satisfy any concern over injected fluids moving up hole from the planned P-06B window area. I cannot attach a copy of the SCMT log of 7/29/05 but I will have a copy delivered to you this afternoon. Please call if there are further issues to work on this one. Ted Stagg 564-4694 office 240-8074 cell ~~L. --... ~~~ 3U PBU P-06B ~'~~ _ ~~ Proposed WAGIN : ~„~-~_ 'I I ta'3'2-1,u-11-131 ' P Q~g ~ P-nZ~y ~ 2051380 Od f P Q1 ~ i ,r T11N, R13F, UM Confidential `~~ ,, Area of Review . K ~ SFD 9/2112005 P-I~y~ r Mww 7 . ' '~~, ~ P--i-~L1 ., j+l /'rte- '~`\` ~~-4_ "', , .,~ P-24 1 ~ ~ /' ~ ~ • 1 -~. ~,~ - ~ P=4~4...., rr ++~~ ma'r' ~~•~,.._f_~-`"^r~ PUT RI'v 33-i t-13 +'-_ ''r 1 `-.`~. _~~.~---~` --~ X-28 -~-.-~---_ tai,, ~' / ' P-~9 6 ~ ~ i i .fem.}'-~,'1~-i'~~ 1 ~ J! 'i'. p-i7 r I~~ it ~r E ~ C f -_._ 'r'- i t -- 7 ... - ., ____ _ _ _ .,~ ~~\_ __ -- _ i ~ _ ~- C. ~ + ~ ' ~ ~ ~"`- I, ~' ~ ~ HU L Sf 5-10-13 r ~ ~ r~ IY Y~~4 'f-~~ T `~. ~ • • 89-6!1252 224 TERRIE L RUBBLE BP EXPLO'RATIQ B A5 INC "Mastercard Check': , ~(~, PO BOX 1-96612 M DATE t ANCHORAGE, AK 99519-6612. ~- C~ $ ~~' PAY TO THE DOLLAR ORDER OF - First National Bank Alaska ~ // .~.~_ C1 L6~n Anchors e, AK 9950:1. ~~~"/,~-'L"`c MEMO ~~~ ~ • 00060:99 L4~•~6 2 27.~~ L 556~~` 0 2 2-. r.L252 • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~ PTD# Z ~ S ' 13~~,, CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f,, all (pig 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). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C1j ody\trans m ittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL -640150 Well Name: PRUDHOE BAY UNIT P•066 Program SER Well bore seg ^ PTD#:2051380 Company BP EXPLORATION (ALASKA) INC Initial ClasslType SER / PEND GeoArea 890 Unit 11650 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_feeattached________________________________ _____________ Yes_ ___-________-____--_-_-_--__.__. ------------------------------------------ 2 Lease number appropriate - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - -- -- -- - 3 Uniquewell_nameandnumber------------------------- ------------- Yes_ ___-__-__--___-_ ---------------------------------------------------------- 4 Well located in a_defnedpool__________________________ _____________ Yes_ -_---_PRUDHOEBAY,PRUDHOEOIL,640150____________-______-___-----__--______--.- 5 Well located proper distance from drilling unit_boundzry_ - Yea _ _ _ - - - _ Governed by CO 341 D: No restrictions as to well spacing except that no pay open closer than-500' to _ . - 6 Well located proper distance from other wells----------------- -------__ Yes_ _-___externalboundary, which is 16,500'away,___-__-----__--__-----___________-_-_--- 7 Sufficient acreageavail_ablein_drillingunit___________________ ____- --__- Yes- -___-_-_-_----_-____-._ 8 If deviated,is_wellboreplatinc_Ilu_ded___-_-__-_----------- ------------- Yes_ _________________ --------------------------------------------------------- 9 Operator only affected party - - Yes - - - - - - - - - 10 Operatothasappropriate.bondinforCe---------- -- ---- -------- --- Yes. -------------------- --- ---------------- ------------------------ ---- 11 Permit_canbei_ssuedwithoutconservationorder--------------_ _____--__ Yes_ _______ -_--------.-_---_--__--__-_____-...--_-- -------------------------- Appr Date 12 Permit_canbeissuedwithoutadministrativ_e_appr_oval__________ _____________ Yes_ _________-_________------__.-_---------__-__________-___-----._...---__ SFD 9121!2005 13 Can permit be approved before 15-day wait Yes 14 -Well located within area and strata authorized by_ Injection Order # (put 10# in-comments)-(FQr- Yes - - - - - _ -Area Injection Order No._3, which governs the Weskem Qpetating Area-- - - - - - - - - - - - - - - - - - - - - - - - - - 15 All wells within 114-mile area ofreyiewident[Pied(Forservicewellgnly)-- ------------- Yes. - ___________-_______________._--_---_......... ----------------------------- 16 Pre-produced injector; dur_ation_ofpve-production Less than 3 months_(For _service well only) _ - Yes - - - - - . _Ted-Stagg; this well will be preptoduced, may_~ up to 3 months duration- - - - - - - - - - - - - - - 17 ACMP_FindingofConsistency_hasbeenissued-forthisp[oject----_-_ -_-_--_-__ NA__ ______Re-drill of existing well,______-______________________________________________ Engineering 18 Conducto[st[ing_provided____________________________ _____________ NA__ ___-_---____ 19 Surface casing_protects all-known USDWS - - - - - - - - - - - - - - NA - - - - 20 CMT-vol_adequate_toci[culate_onconductot&surf_csg__--__-,__ _--_------__ NA__ _______- _________________________________---------_-__ --------------- 21 CMT-voladequate-tolie-in long string to surfcsg_-_----------- ------------- NA__ --__--___-__________ - -- -- -- 22 CMT willcoyerallknownproductiyehorizons-_-_--__________ _____________ Yes_ ______Adequateexcess,-__-_---_---_------_----_-________--__--_----------_____ 23 Casing designs adequate for C,T,B&_permafcost-------------- ------- Yes- ------------------------------------------------------------------- 24 Adequatetankage_orreseruepit-_____---------------- ------------- Yes_ ____--CTDU.____________________ -------------------------------------------- 25 If_a_re-drill,has-a10.403for abandonment been approved_________ _____________ Yes_ --__-_9120/2005:..__.__..__.-__.-----_-______-___--____-.------.-__-___-__.-- 26 Adequatewellboreseparation_Proposed-------------------- ---------- -- Yes- --------- ---------- -- -- ----------------- -...-- --- ---------- ----- 27 Ifdiverterrequired,doesitmeetregulations---------------_- __--____---_ NA-_ ______Sidetradc.________--_-_--,_---------------_-______--_.-___------_---_ Appr Date 28 Drillingfluid-program schematic&e4uiplistadequate------------ ------------- Yes_ _____-Max MW 8.6ppg.___________--__.__..-__--___--_--_-_---------_ -_ WGA 9122!2005 29 BOPES,dotheymeetregulation_______________________ _____________ Yes_ __-_-___--__--__-__--_---__-____--_-__________-__-___.._. 30 BOPE_pressratingappropriate;testto-(putpsigincomments)_______ _____________ Yes_ ___-_Testto 3500_psi._MSP22.40psi.________---_--_--__--__-____________---_--_--_ 31 Choke_manifoldcomglieswlAPIRP-53(May84)_______________ _____________ Yes_ -_-___________________..-_._-_-__--__-__-._-_-_______-_________--__ 32 Work willaccurwithoutoperationshutdown__________________ _____________ Yes_ __-_________________-___-__-_- ------------------------------------------- 33 Is presence- of H2S gas_ probable - - - - - - - - - - - - - - - - - Yes - ~? Ppm• - - - - - - - - - - 34 Mechanical condition of wells within AQR verified (FOr_service well only Yes - . - _ - .. No wells within AOR- - - - - - - - - - - - - ---------------------------------- Geology 35 Pennit_ean be issued wlo hyd[ogen_sulfiderneasures - - - No_ - _ - _ _ - - H2$ has been measured up to 20 ppm on P-Pad.- 20 AAC 25.065(b) states that if a well_is to be drilled where a _ _ 36 Data-presented on-potential overpressure zones Yes - - _ _ - . -formation is known to contain_H2S, API's RPI 49 recommended practices-will be followed._ Reservoir is under-- - - Appr Date 37 ------- Seismic analysis of shallow gas-zones - - . - - - - . - - - ------------- -KA__ __pressured(6.8ppgEMW);willbedrilledwith8.tppg.mud,-_-._________-__-_-___- ---------- SFD 9121!2005 38 Seabed condition survey-(ifoff_-shore)_____________________ ______--.-_. NA__ --_-.-_--__---_--_-________-_____ 39 _ Contact name/phone for weekly progress-reports [exploratory only]- - _ - - NA_ Geologic Engineering Commissioner: Date: Date Commissioner: m' Date er • • Well History File APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jul 31 14:31:51 2007 Reel Header Service name .............LISTPE Date .....................07/07/31 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................07/07/31 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA Scientific Technical Services Scientific Technical Services P-06B 500292216602 BP Exploration (Alaska) Inc. Sperry Drilling Services 31-JUL-07 MWD RUN 1 JOB NUMBER: W-0004005436 LOGGING ENGINEER: B. JAHN OPERATOR WITNESS: S. NOYNAERT/ SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 3I 11N 13E 2506 1963 92.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 4.125 5.500 9976.0 2ND STRING 3RD STRING PRODUCTION STRING Vi. C ao 5 - ~ 3'~s ~ ~s3z~S REMARKS: • 1. ALL DEPTHS ARE BIT DEPTHS (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 9976'MD/ 8808'TVDSS IN THE P-06 WELLBORE. 4. MWD RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER OPEN-HOLE GAMMA RAY LOG RUN IN P-06 ON 19 MAY 1991. THESE PDC DATA WERE PROVIDED TO SDS BY D. DORTCH ON 15 JUNE 2007, QUOTING AUTHORIZATION FROM COLE ABEL (BP GEOSCIENTIST). LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THE SHIFTED SGRC LOG IS CONSIDERED THE PDC LOG FOR P-06B. 6. MWD RUN 1 REPRESENTS WELL P-06 B WITH API#:50-029-22166-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11800'MD/8941'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/31 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9951.0 11754.0 RPD 9960.0 11767.0 RPM 9960.0 11748.0 RPS 9960.0 11766.5 • • RPX 9960.0 11748.0 FET 9960.0 11767.0 ROP 9994.0 11799.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 9951.0 9950.0 9951.5 9950.5 9954.0 9953.5 9959.0 9959.0 9962.5 9962.5 9965.5 9965.0 9971.0 9971.0 9973.0 9973.5 9975.5 9975.5 9978.0 9978.5 9979.5 9980.0 9981.5 9982.5 9984.0 9984.5 11799.5 11800.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 9950.0 11800.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9951 11799.5 10875.3 3698 9951 11799.5 RPD MWD OHMM 0.27 2000 54.2136 3615 9960 11767 RPM MWD OHMM 0.63 2000 27.9503 3577 9960 11748 RPS MWD OHMM 0.61 2000 22.7028 3614 9960 11766.5 RPX MWD OHMM 0.21 2000 20.4751 3577 9960 11748 FET MWD HOUR 0.01 4.5 1.21935 3615 9960 11767 GR MWD API 10.12 441.22 62.8716 3607 9951 11754 ROP MWD FT/H 0.43 1229.11 68.4705 3612 9994 11799.5 • • First Reading For Entire File..........9951 Last Reading For Entire File...........11799.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/31 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/31 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9950.0 11754.5 RPD 9960.0 11767.5 RPM 9960.0 11748.5 RPS 9960.0 11767.0 RPX 9960.0 11748.5 FET 9960.0 11767.5 ROP 9994.5 11800.0 LOG HEADER DATA DATE LOGGED: 25-OCT-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11800.0 TOP LOG INTERVAL (FT) 9950.0 BOTTOM LOG INTERVAL (FT) 11800.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 44.4 MAXIMUM ANGLE: 102.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 78005 EWR4 ELECTROMAG. RESIS. 4 178425 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 • • DRILLER'S CASING DEPTH (FT) 9976.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S) 50.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3) 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .080 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .030 167.7 MUD FILTRATE AT MT: .150 65.0 MUD CAKE AT MT: .120 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 1 68 16 5 FET MWDO10 HOUR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MWDO10 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9950 11800 10875 3701 9950 11800 RPD MWDO10 OHMM 0.27 2000 54.8084 3616 9960 11767.5 RPM MWDO10 OHMM 0.63 2000 28.7033 3578 9960 11748.5 RPS MWDO10 OHMM 0.61 2000 23.9803 3615 9960 11767 RPX MWDO10 OHMM 0.21 2000 20.6286 3578 9960 11748.5 FET MWDO10 HOUR 0.01 4.5 1.21957 3616 9960 11767.5 GR MWDO10 API 10.12 4 41.22 62.8609 3610 9950 11754.5 ROP MWDO10 FT/H 0.43 12 29.11 68.4705 3612 9994.5 11800 First Reading For Entire File..........9950 Last Reading For Entire File...........11800 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/31 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/07/31 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................07/07/31 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File