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197-001
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU G-32A Cement Squeeze Perfs, Mill Plugs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-001 50-029-21636-01-00 12220 Conductor Surface Intermediate Liner Liner 9025 80 2644 8743 586 3815 12125 20" 13-3/8" 9-5/8" 7" 2-7/8" 9026 41 - 111 40 - 2684 36 - 8779 8529 - 9115 8405 - 12220 41 - 111 40 - 2680 36 - 8423 8195 - 8733 8080 - 9025 12118 470 2670 4760 5410 11160 None 1490 5380 6870 7240 10570 10740 - 12100 4-1/2" 12.6# L-80 34 - 8589 9014 - 9026 Structural 4-1/2" TIW HBBP Packer 8470, 8141 8470 8141 Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 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 pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028280 34 - 8251 Perforations 8790' - 8820'MD and 8830' - 8840'MD Squeeze 3.5-bbls of 15.8-ppg Class G cement with final pressure of 2000-psi. 274 1042 36366 27902 15 72 900 1000 700 400 323-398 13b. Pools active after work:Prudhoe Oil No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:41 pm, Sep 26, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.09.26 14:25:42 -08'00' Torin Roschinger (4662) DSR-9/27/23 RBDMS JSB 100323 WCB 4-11-2024 This is just the first part of Sundry 323-398. The rest of the work is to be squeezing and adperfs. -WCB ACTIVITY DATE SUMMARY 9/18/2023 CT #9 1.75" 0.156" Coil Tubing - Job Scope: Cmt Sqz Sag, Mill 2 CIBP, Cont Adperfs, & N2 Lift Mobilize CTU 9. ***Continue on WSR 9/19/23*** 9/19/2023 CT #9 1.75" 0.156" Coil Tubing - Job Scope: Cmt Sqz Sag, Mill 2 CIBP, Cont Adperfs, & N2 Lift Complete RU CTU 9. MU Slb BHA w/ 2.28" BDJSN. Kill well. RIH. MIRU HES Cmt. Tag CIBP 8927 ctmd. Flag coil 8780. Park at top of the liner 8405. Load the well with 104 bbls diesel. Pump 15 bbls 15.8 class g cement. Bullheaded 2 bbls behind pipe and laid in the rest. Pressure up to 2000 psi and maintain squeeze for 50 minutes. Bled pressure down and contaminated the cement in the tubing. Tagged 8824' ctmd. Could not get it jetted off. Chase out to surface. Perform 1500 psi test at surface. MU YJ milling assembly w/ 2.3" 3 bladed junk mill. RIH. Tag at 8803 ctmd. PUH and start milling ***Job Continued on 9/20/23*** 9/20/2023 CT #9 1.75" 0.156" Coil Tubing - Job Scope: Cmt Sqz Sag, Mill 2 CIBP, Cont Adperfs, & N2 Lift Milling Cmt from 8802' to 8847' CTM. Mill on CIBP @ 8916' MD. Thru CIBP 1hr 10 mins. Push down to 11,336.7' CTM. POOH. BD YJ 2.30" 3 blade Rev Clutch Mill (good wear). MU 2.30" Venturi / Burn shoe w/ 3' extension barrel. RIH. Tag @ 11,340.2' CTM / 11,340' Mech. Milled 1-1/2 hours - 3 stalls, went time milling. End just stacking limited motor work. RIH and stacked down twice. POOH. BD Venturi / Burn shoe. Btm burn shoe wore down flat. Nothing in flutter cage. Six to Seven metal slip parts and top piece of the core in barrel and grey silt. MU new 2.30" Venturi / Burn shoe. RIH. Tag @ 11,330' CTM. Mill w/ limited MW, stacking weight continuously. POOH, nothing inside basket. Stack down, change packoffs. M/U YJ Milling BHA ***Continue to WSR on 9/21/23*** 9/21/2023 CT #9 1.75" 0.156" Coil Tubing - Job Scope: Cmt Sqz Sag, Mill 2 CIBP, Cont Adperfs, & N2 Lift MU YJ milling BHA, RIH, tag at 11,338'. Start mill w/ 2.3" 3 blade rev clutch mill. Milled for 2 hrs w/ 6 stalls. putting wgt down no stalls. RIH tagged pumping and dry @ 11,340.7' CTM. Pulled heavy, stuff followed up hole. Stalling @ 11,334.5', made to 11,335' w/ 18 stalls (total of 25 stalls). POOH. Pulled tight from 9538' thru 9272'. BD YJ 2.3" rev clutch mill. MU 2.30" Venturi / burn shoe. RIH. Tag @ 11,341' CTM / 11,346' Mech. Broke thru CIBP. Pushed to 12,128' CTM / 12,118' MD. POOH. L/D YJ tools, had various debris inside venturi and end of burn shoe packed off. ***Continue to WSR on 9/22/23*** Daily Report of Well Operations PBU G-32A Milling Cmt from 8802' to 8847' CTM. Mill on CIBP @ 8916' MD. Thru CIBP 1hr 10 g mins. Push down to 11,336.7' CTM. POOH RIH, tag at 11,338'. Start mill w/ 2.3" 3 blade rev clutch mill.gg Milled for 2 hrs w/ 6 stalls. putting wgt down no stalls. RIH tagged pumping and dry gg gg g y @ 11,340.7' CTM. Pulled heavy, stuff followed up hole. Stalling @ 11,334.5', made@yg@ to 11,335' w/ 18 stalls (total of 25 stalls). POOH. Pulled tight from 9538' thru 9272'. () g BD YJ 2.3" rev clutch mill. MU 2.30" Venturi / burn shoe. RIH. Tag @ 11,341' CTM / g@ 11,346' Mech. Broke thru CIBP. Pushed to 12,128' CTM / 12,118' MD. POOH gj MU YJ milling assembly w/ 2.3" 3 bladed junk mill. RIH. Tag at 8803 ctmd. PUH and start milling Coil Tubing - Job Scope: Cmt Sqz Sag, Mill 2 CIBP, gy RIH. Tag @ 11,330' CTM. Mill w/ limited MW, stacking weightg@ continuously. POOH, nothing inside basket. Stack down, change packoffs Daily Report of Well Operations PBU G-32A 9/22/2023 CT #9 1.75" 0.156" Coil Tubing - Job Scope: Cmt Sqz Sag, Mill 2 CIBP, Cont Adperfs, & N2 Lift Continue weekly BOP test. M/U SLB BHA, RIH. N2 lift ***Job Complete*** 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU G-32A Extended Perf w CTU, Mill CIBPs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-001 50-029-21636-01-00 341J ADL 0028280 12220 Conductor Surface Intermediate Liner Liner 9025 80 2644 8743 586 3815 8915 20" 13-3/8" 9-5/8" 7" 2-7/8" 8552 41 - 111 40 - 2684 36 - 8779 8529 - 9115 8405 - 12220 2100 41 - 111 40 - 2680 36 - 8423 8195 - 8733 8080 - 9025 11330 470 2670 4760 5410 11160 8915, 11330 1490 5380 6870 7240 10570 8790 - 12100 4-1/2" 12.6# L-80 34 - 85898437 - 9026 Structural 4-1/2" TIW HBBP Packer No SSSV Installed 8470, 8141 Date: Torin Roschinger Area Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY 7/28/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:14 am, Jul 14, 2023 323-398 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.07.14 10:57:21 -08'00' Torin Roschinger (4662) MDG 7/21/2023 MGR14JUL23 10-404 DSR-7/19/23 2100 GCW 07/24/2023JLC 7/24/2023 07/24/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.24 10:01:53 -08'00' RBDMS JSB 072523 Sqz, Mill Plug & Ext AdPerf Well: G-32A Well Name:G-32A API Number:50-029-21636-01 Current Status:Shut in – HGOR Pad:G-Pad Estimated Start Date:9/1/2023 Rig:C, S Reg. Approval Req’d?10-403 & 10-404 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:197-001 First Call Engineer:Michael Hibbert Contact:907-903-5990 Expected Rates:30 MMCFD, 600 BOPD, 5% WC Current Bottom Hole Pressure:2815 psi SBHPS – 12/13/19 MPSP:2100 psi (BHP - .1psi/ft gas gradient + safety factor) Bottomhole Temp:186 deg Max Dev:95 deg At 10,184’ MD Min ID:2.37” ID of 2-7/8” x 4-1/2” Liner Hanger Pkr at 8,405’ MD Brief Well Summary: G-32A is a February 1997 CTD sidetrack which targeted Zone 1A/1B reserves. The well came on strong and production has been managed with several PPROFs, multiple Add Perfs, several CIBPs and an Organoseal/Squeezecrete job in 2013. In September 2015 Sag perfs were shot, which stayed competitive through mid-2019. Well has had very little on-time since then. Objective: Squeeze open perforations in the Sag/Shublik. Mill 2 CIBPs and add perforations to increase well on-time and decrease GOR. Mill WFD CIBP at 8915’ and CIBP at 11,330’ and push all debris to PBTD at 12,125’. Contingent plan to add following perforation intervals if lower CIBP can’t be milled and pushed downhole: 168’ Z1B 10670’ – 10838’ MD, 200’ Z1B 10100’ – 10300’ MD, and 35’ Z1B 10030’ – 10065’ MD. NOTES: x Well does not have any GLMs so it likely will need a N2 lift to kick off, particularly since a large amount of fluids will be pumped while milling CIBPs. x 3 fish are sitting above CIBP at 11,330’ including 1 stiffener ring and 2 milled CIBPs. The 2 milled CIBPs were milled/pushed downhole in 2013. x If progress stalls while milling CIBP at 11,330’ stay in close contact with OE to decide when to abort that objective and proceed with the contingent adperfs. x Recently, we had issues with HES cement thickening early on U-09, D-16, and W-40. We were not able to contaminate the cement and milling was required. o Work with HES on appropriate method for TT lab testing. The plan is to lay in the cement prior to beginning squeeze. Assuming 0.5 bpm while laying in cement, we will have at least ~30 min. static time prior to final pumping. This static period should be mimicked in the lab. o If Class G cement is used, work with HES to ensure accurate amounts of liquid retarder are added to ensure TT is not inadvertently reduced. o K-09 and potentially E-03 are other Sag squeezes that will likely have been completed prior to G- 32A squeeze. Review results of K-09 and E-03 for lessons learned. Procedure: Coil – Cement Sag/Shublik Perforations: 1. MIRU CTU – include considerations for the following in the rigup: a. Cementing b. Extended perforating deployment c. Nitrogen lift to kick well off Sqz, Mill Plug & Ext AdPerf Well: G-32A 2. RIH with nozzle and dry tag CIBP at 8,915’. PUH and paint flag above top perforation at 8,790’. a. Tagging CIBP will confirm that the plug has not moved and is still intact. 3. Perform ~ 156 bbls (1.2x tbg vol to top perf) well kill down the CTBS with 1% KCL at max rate up to 2,000 psi. a. If low injectivity prevents killing the well by bullheading (<1 bpm injectivity at 2000 psi max pressure), RIH with the CT and circulate the gas from the wellbore by pumping 1% KCL down the CT and up the BS. If this step is needed, plan to reciprocate 12% HCL across perforations to improve injectivity prior to pumping cement. 4. Pump 104 bbls diesel down the backside to underbalanced the well. a. Targeting 100 psi of WHP, but this well appears to have a depressed SBHP and may be close to balanced even with diesel. b. Adjust diesel volume as needed. 104 bbls calculation assumes 1.75” coil inside 4-1/2” tubing to 8405’ and then in 2-7/8” liner down to 8790’. 5. MU nozzle and RIH to ~8,890 MD (~50’ below perforations we are squeezing from 8790’-8820’ MD and 8830’-8840’ MD). SD pump to obtain static baseline pressure. 6. Batch mix cement. 7. After cement passes QC, pump the following down CT: a. 10 bbls freshwater spacer b. 15 bbls of 15.8 class G cement i. D-13 and G-29 were recent Sag squeezes. D-13 got 8 bbls cement behind pipe in 30’ of perfs, and G-29 got 6 bbls cement behind pipe in 60’ of perfs. ii. WCS TOC if no cement goes into the perfs is ~7615’ MD. c. 10 bbls freshwater spacer d. Powervis for contaminate and 1% KCL for coil displacement. 8. As cement reaches the nozzle, position the coil at ~8,890’ MD. Open the choke and allow 1 bbl of cement to circulate above the nozzle and then begin pulling OOH while laying in the cement 1:1 until nozzle is above the tops perfs at 8,790’ MD. 9. Shut in the choke and begin squeezing cement into the formation. Keep choke closed until initial squeeze pressure has been achieved. Squeeze pressure = 500 psi higher than static baseline pressure from step 5. 10. Open the choke and lay in all remaining cement and PUH to safety while attempting to maintain initial squeeze pressure. 11. Once at safety, close the choke and begin to ramp up pressure in ~500 psi increments lasting 5-15 min each. Final target squeeze pressure is ~2000 psi. Hold final squeeze pressure up to 60 min. if thickening time allows. a. D-13 and G-29 recent Sag squeezes were both able to achieve a 2000 psi squeeze. b. Due to the Sag being relatively low perm, we should achieve squeeze. In the event the well does not squeeze off after 12 bbls, attempt hesitations. 12. Contaminate down the coil with Powervis at max rates taking the returns up the backside. Jet from the safety depth to CIBP at 8,915’ MD. Make a couple up/down passes while jetting. Reduce rate <1 bpm across the perfs from 8790’-8820’ MD and 8830’-8840’ MD. 13. Do small PT to 1500 psi to confirm cement squeeze was successful. Contact OE if PT does not pass or if we were not able to build squeeze pressure while pumping cement. Likely we will try to resqueeze. 14. Chase out of the hole from CIBP at 8,915 MD to surface with 1% KCL. Make double passes across all jewelry. Once at surface and swab is SI, wash BOPS. Sqz, Mill Plug & Ext AdPerf Well: G-32A Coil – Mill CIBPs: 15. MU 2-1/8” motor with 2.30” venturi/burn shoe. If a good cleanout down to the CIBP at 8915’ wasn’t achieved post-squeeze then consider running a mill instead of venturi/burn shoe. 16. RIH and burn over WFD CIBP at 8915’. Push downhole and attempt to recover core. a. Continue running venturi/burn shoe BHAs until progress stalls. b. Swap to mill at WSL discretion. c. Attempt to recover all fish above CIBP at 11,330’. d. Mill and push CIBP at 11,330 to PBTD. e. If up to date spend reaches $245k call and discuss plan forward with OE, may abort milling CIBP at 11,330’ if options have been exhausted. Coil – Contingent Extended Perforating – Execute if lower CIBP at 11,330’ is not milled and push to bottom Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. Bullhead ~225 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 130 bbls b. 4-1/2” Tubing/Liner – 8,405’ X .0152bpf = 127.8 bbls c. 2-7/8” Liner – 385’ X 0.0058 = 2.2 bbl 3. MU and RIH with GR/CCL with 2.25” JSN. 4. Flag pipe as appropriate per WSS for adperf 5. POOH and freeze protect tubing as needed. 6. Confirm good log data. 7. At surface, prepare for deployment of TCP guns. 8. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. a.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 10.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Sqz, Mill Plug & Ext AdPerf Well: G-32A Perf Schedule Use 2” Max Force guns or similar Perf Interval Perf Length Gun Length Weight of Gun (lbs) Run #1 10,670’ – 10,838’168’168’840 lbs (5 ppf) Run #2 10,030’ – 10,065’ 10,100’ – 10,300’ 235’ 270’ 1350 lbs (5 ppf) 11. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 12. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 13. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 14. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 15. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 16. MU Run #2 BHA and repeat process for starting with step #11. Coil – Nitrogen Lift: 17. MIRU portable test unit with G-12 as the potential outlet well. 18. MU ~2” nozzle and lift well with N2 until well is flowing on its own or until most fluids lost to the well are recovered. 19. RDMO CTU. 20. Turn well over to Operations to continue flowing. SL: 1. Set dreamcatcher at 2089’MD if plug debris not able to be pushed to TD. SP: 2. Pull dreamcatcher if set. Attachments: x Current Schematic x Proposed Schematic – All CIBPs milled, No Extended Add Perforations x Proposed Schematic - Contingent Extended Add Perforations x CT BOP Schematic x Standing Orders for CT Extended Length BHAs x Site Layout Diagram x Sundry Change Form Sqz, Mill Plug & Ext AdPerf Well: G-32A Current Schematic: Sqz, Mill Plug & Ext AdPerf Well: G-32A Sqz, Mill Plug & Ext AdPerf Well: G-32A Proposed Schematic – All CIBPs Milled: Squeeze Perf from 8790’-8820’ and 8830’-8840’ Mill and push to PBTD or recover all CIBP/fish Sqz, Mill Plug & Ext AdPerf Well: G-32A Proposed Schematic – Contingent Extended Add Perf: Sqz, Mill Plug & Ext AdPerf Well: G-32A BOP Schematic Sqz, Mill Plug & Ext AdPerf Well: G-32A Sqz, Mill Plug & Ext AdPerf Well: G-32A Sqz, Mill Plug & Ext AdPerf Well: G-32A Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date STATE OF •ALASKA OIL AND GAS CONSERVATION COMMISIN RECEIVE REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed NOV 0 6 2017 Abandon 0 Plug Perforations I! Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Chan.: •4?1• q�o�re 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set B v m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 197-001 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21636-01-00 7. Property Designation(Lease Number): ADL 0028280 8. Well Name and Number: PBU G-32A 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 12220 feet Plugs measured 8915/11330 feet true vertical 9025 feet Junk measured See Attachment feet Effective Depth: measured 8915 feet Packer measured 8460 feet true vertical 8552 feet Packer true vertical 8131.45 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 31 -111 31-111 1490 470 Surface 2650 13-3/8"72#L-80 30-2680 30-2680 4930 2670 Intermediate 8746 9-5/8"47#L-80 28-8774 28-8423 6870 4760 Production Liner 3815 2-7/8"6.5#L-80 8415-12230 8089-9025 10570 11160 Liner 594 7"26#L-80 8521-9115 8188-8733 7240 5410 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 26-8579 26-8242 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: ��magi DE 2 VOL, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 802 61476 15 600 962 Subsequent to operation: 771 60004 10 800 949 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development II Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil IZI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Alatalo,Travis Contact Name: Alatalo,Travis Authorized Title: Production Engineer Contact Email: Travis.Alatalo@bp.com Authorized Signature: �y, Date: lC b� Contact Phone: +1 9075645351 Form 10-404 Revised 04/2017 V rL /Z! /� �� ,� - l)I /� �, Rez,T,5 J � Ia --j 7 ubmit Original Only Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary October 30, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for the Setting of a Cast Iron Bridge Plug (CIBP) for Well G-32A, PTD # 197-001. 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 • S Junk Attachment PBU G-32A SW Name MD Date Comments G-32A 11329 08/20/2013 Milled CIBP G-32A 11329 11/20/2013 1/2"x 6" Stiffener Ring G-32A 11329 08/28/2013 Milled CBP G-32A 12133 07/12/2003 Milled CIBP • • a) H m• 00 N 00 Nto Co r N 00 0 UD LID 00 N P- co r- r` CO UD LID O CCn CO CO00 N Nt Tt CO 00 Cr r N N- O O N-Co U3 00 M CO 'r 0 C) O O m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Co c0 Co O O 0 0 0 0 0 0 0 0 0 0 0 O O O O MM 0. 0 1- CO CO LID 00 (O r` P. CO r` r r` 00C, 0 CO N r` Co CO r` r` O .c O N- O CO r CO') LC) r 0 Co M Co 0 U, r` O O Co N- N CO Q r` CO N CO M O O CO 00 c0N M �' O N �t M4 Lo r` 0 cd d M r` 0 0 0 0 0 0 r r r r O r N N N M M M M N 0 ,4 [t 00000000000000000000000 o 0 c0 0 0 0 0 0 0 0 0 0 0 O O O O O O O O O 0 m N R L• 0 0 0 0 ,rr` C v- to 0 Co Co M 0 0 0 O c0 0 co O Co O O O ++ rCONv- 00MCb � r- OrN , v- r- NrO W Co Co Co C0 O Co 0 0 r r r r N CO O cO O O O O O O _ O r d Co M C) 0 C) 0) 0 0 0 O O O O O O O O O O .r . r (Ni O Co O O O O r r r r . . . . . r r . . . . . . . r E t 2 •s M C r o 0 0 o v r• Co '� u) U, UD CO O O O O Co Co O Co Co Co O O 0. O N co N _O N_ d' U) r CO r` 00 r r r r- O CD O M 00 o0 Co Cn (O CO 0, 0 0 0 0 0 co O O O O O O O O O O O CO 0 W N 000000000 Ma0) L d O 2 . a a) 0 C.) O LL LL U) U) C/) C/) C/) C/) U) C/) C/) CA C/) C/) U) C/) U) U) C/) C/) C/) U) C/) C/) U) (1aaaaaaaaaaaaaaaaaaaaaa. aCLa 0. 0 t d a R• U) o r, r` r` r` r` r` r` r` r` r` r` r` r` r` r` r` r` r` r` r` r` r` N- 0 c 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O N N N N N N N N N N N N N N N N N N N N N N N N N a' V- V- N N- N- N- N- ` N- N N- N- - N- N- N- N- N- N- N- N- - N .- r r N N N N N N N N N N N N N N N N N N N N N N N a 0 O 0 Co inU) to ) to U) 0 ) Co to Co 0 U) Co U) Co to U) U) Co Co 0 a) E R Z Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q 3 N N N N N N N N N N N N N N N N N N N N N N N N N N C'7 C') M C'7 M M M M M M M C') M M M M M M M M M M M M Cr) • ❑ w 0 w ❑ w Z Lu I- H a 5 5 Y U O > O O WJ Y Y cn cn U U w w J J J a s VI Z ¢ ¢ ¢ W O J 0 U U J W W J J ¢ ¢ ¢ I a 0 a W O• 00W & & Z O Z 2 2 2 0 <n cn cn U) U = a J a 2 2 2 0 v) m cn cn cn ❑ w J D co I- w 00 O❑ ❑ ❑ ❑ O a a W N N lL ❑ W W W J W W Z• 0_ 00C)W Wu_ W CO• ❑ E J -10 d W W • < 1:0 m L L <n cn a s lL a U) OlLI- N LL ¢ ¢ COw J LL COvv) 0) 0 a Ce • • Packers and SSV's Attachment PBU G-32A SW Name Type MD _ TVD Depscription G-32A PACKER 8422.74 8096.58 2-7/8"TIW Packer G-32A TBG PACKER 8460.21 8131.45 4-1/2"TIW HBBP Packer . . J• J U) U) o o s O O U) O O n c ci H I- I-• oa m cc cc w w 2 0 LL J_ J_ 1, H Q Qv 0 Z' C m m 0 - E -41 w b 0 i 2 d 0• m 0 = 0- a 2 fn in in Z I) 1- 0 D N N d -0 Q U) N J N M Q 5 N X U) X °D p L� ,,G, M ao p ao @ O Q * a m d %.- = x* j� a � J � w O E _ C Ce O > d w a M 2 ce VOV ~ m wa) Q NUCLZ N CM• O N p N O Q 0 X MX Z °O Z � N � �U) § 2 co- 2 = d OI- JI- a`omt -1 § m § N U w J WCV zwC� °' (Ni N * PE < IM < lj * _N : areal- U) * 0 w 1- < N- 0 0 N Ta 5_ N I LU 0 a TREE= 4'OW • WELLHEAD= MVEVOY G-32A S NOTE_ URDSIDEtRACKCOMPLETION ACTUATOR= OW "•WELL ANGLE>700 I19459"" OKB.ELE1/= 72.3' i BF.a Eli= _.._._, 35.92' KOP= _ 4192' 2089' H4-1/2"1-1)(0 SSSV P ',D=3.813" Max Angie= —95'410184' GO Datum MD=�__ 9269—' [tum TVD= 8800'SS ' 13-3/8'CSG,72#,L-80,D=12.347" H 2884' 9-5/8"CSG,47#,L-80,ID=8.681' H 4268' X I ' I 8396' H4-1/2'O11S XA SLD SLV,D=3.813" TOP OF 2-7/8"LN2 H 8405' 8405' H4-1/2*X 2-7/8'R< 143R VV/T1133ACK,D=2.370" so es 8425' HTOC N 4-1/2"X 2-7/8'ANNULUS Minumum ID =2.37"@ 8405' ,. 14 • 04 2-7/8" LINER TOP,PIN ID . 1.•,,• 8455' TW SBR TBG SEAL ASSY .. 1$, ►�,. 14C7. 8470' -I9-58'X 4-1/2"TWW HEP ROT,D=4.750' I $. • ••�•� ; 8518' H 41/2"011s X NP,ID=3.813' TOP OF r LMt H 8525' -•,* ! ► y'• BEHIND I►�1 ,.1 8555' 4-1/2"MLLE 0715 XN NP,D=3.8' CT LNR •►• 1.1•/ 4-1/2"TBG,12.6#,1-80,.0152 bpf,D=3.958" H 8589' ,;.�i 1444 8589' H4-1/2"WLEB,D=3.958' ►••. 1••, ►• 19-5/8"CSG,478,1-80,D=8.681" H 877 19' •%i I.*/i 8120' M Ill II, �':,: :r-y�•'�a ►•i! 7' ►• ILMt,26#,L-80..0383 bpf,D=6276' H —9116 �••�•i ,••-• _ ► 8915' H2-7/8'WFDCOP(05/27/17)I �•�� oltt SDETRAO(WIDOW (G-32A)9115'-9122' ,ii i:11/ PERFORATION SUMMARY RIFF LOG:SPERRY SW MUYDGR ON 01/25/97 ANGLE AT TOP FEW:23'@ 8790' Pbte:Refer to Production OB for historical pert data SIZE I SPF 1 INTERVAL I OPNSQZ I SHOT I SOZ SEE PAGE 2 FOR PERF SUMMARY ' I1 1 I I I ? HFISH-1/2"X 6"STIFFENER RING(11!20/13) 1 I 11330' --IFISH-MILL&PUSH CEP(08/27/13) d 11330' HASH-CEP MLLE)&PUSI- O TO TD(08/20/13) 11330' H2-78"CEP(01/18109) Pi 12133' —I FISH-CEP MILLED&PUSH®TO TD(07112/03) .r.{ MID 12125' 2-7/8"LNR,6.56,1-80,.0058 bpf,D=2.441' H 12220' 100 - DATE REV BY COMMENTS DATE REQ/BY COMMENTS PRUDHOE BAY &NT 08/22188 ORIGWAL COMPLETION '07/26/17 RCB1JMD CORRECTED CEP DEPTH TYPO WELL G-32A 02120197 TIRO MDETRACK COMPLETE PERNIT Mt:'1970010 12/03/13 LIYJMD FBF SOZ CORRECTIONS(08/22/13) AR Pb: 50-029-21636-01 10/02/15 DHS/J114)ADPERFS(09/14/15) S& 12,T11 N,R13E.1922'SNL&4312'WEL 05/09/16 RB/..ND TREE CIO(05/03/16) 05/31/17 LG/JMD SET CEP(05/27/17) BP Exploration(Alaska) G-32A • [1X X •;: OA,, i! Zee Iii►. RPFORATION SPRY ► • REF LOG:SPERRY SUN MAD/GR ON 01/25/97 -40,• i i�1 ANGLE AT TOP PERF:23"at 8790 • ► 1 �/ ., Note:Refer to Production DB for tistorical pert data �4.• 1.14 SIZE SPF INTERVAL ORWSOZ SHOT SQZ (.•� 11/ 7 6 8790-8820 0 09/14/15 '• 114 •! 2 883 6 0-8840 0 09/14/15 A A**. 1���4 2 6 9520-9550 S 07/29/10 08122/13 111 2 6 9620-9650 S 07/29/10 0822!13 1,11, 2 6 9674-9704 S 0729110 08/22/13 e••. 2" 6 9727-9757 S 07/29110 0822/13 •�• 2" 6 9988-10018 S 0729110 0822/13 ••• 1.1 14,4 2 6 10024-10054 S 0729110 08/22/13 ��i! $.*1 2" 6 10105-10140 S 01/18/09 08/22/13 $1,1 2 6 10145-10155 S 01/18/09 08/22/13 ►.� ►144 2 6 10380-10680 S 01/26/01 08/22/13 e••. '�1' 1-11/16' 4 10740-10920 C 02/20/97 2 6 10740-10920 C 01/26/01 2 6 10840-10870 C 11/18/13 2" 6 10670-10900 C 11/17/13 2 6 10888-10918 C 11/16/13 1-11/16' 4 11010-11120 C 02/20/97 7 6 11018-11048 C 11/16/13 7 6 11048-11078 C 11/16/13 1-11/16" 4 11600-11910 C 02/20197 1-11/16" 4 11960-12100 C 02/20/97 111 I 'IBJ DATE REV BY OOM 34TSi (ATE REV BY COMENTS PRLl)HOEBAY IHT 08/22/86 0 GINAL COMPLETION 07126/17 RCB/JM) CORRECTED CBP DEPTH TY R) WELL: G-32A 02/20187 TTRD SIDETRACK COMPLETE FERRET Pb:'1970010 12/03/13 WIND PEW SOZ CORRECTIONS(08/22/13) AR No: 50-029-21636-01 10/02/15 DHS/JM)ADPERFS(09/14115) SEC 12,T11 N,R13E,1927 SNL&4317 Wa 05/09/16 RB/JM) TREE C 0(05103116) 05/31/17 LG/JM) SET CEP(05/27/17) BP 6rploratfon(Alaska) STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate fZI Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 197-001 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21636-01-00 7. Property Designation(Lease Number): ADL 0028280 8. Well Name and Number: PBU G-32A 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 12220 feet Plugs measured 11330 feet o( r 0 2015 true vertical 9025 feet Junk measured See Attachment feet �> ! Effective Depth: measured 11330 feet Packer measured 8460 feet ,[s'-��p�''�, AOCtrue vertical 9051 feet Packer true vertical 8131.45 feet °p° Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 31 -111 31-111 1490 470 Surface 2650 13-3/8"72#L-80 30-2680 30-2680 4930 2670 Intermediate 8746 9-5/8"47#L-80 28-8774 28-8423 6870 4760 Production Liner 3815 2-7/8"6.5#L-80 8415-12230 8089-9025 10570 11160 Liner 594 7"26#L-80 8521-9115 8188-8733 7240 5410 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet CPV AN 20 °,1 S tid Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 26-8579 26-8242 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 370 30308 7 0 861 Subsequent to operation: Shut-In 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 121 Exploratory 0 Development 0 Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron, Garry R(Wipro) Title PDC Principal Engineer Signature .2atI l // Phone +1 907 564 4424 Date 10/6/15 Form 10-404 Revised 5/2015 VrTL1 l / G5" RBDMSJ'Oa - 7 2015 Submit Original Only i� • • Junk Attachment PBU G-32A SW Name MD Date Comments G-32A 11329 08/20/2013 Milled CIBP G-32A 11329 08/28/2013 Milled CBP G-32A 11329 11/20/2013 1/2"x 6" Stiffener Ring G-32A 12133 07/12/2003 Milled CIBP Packers and SSV's Attachment SW Name Type TVD Depscription G-32A PACKER 8096.58 2-7/8"TIW Packer G-32A TBG PACKER 8131.45 4-1/2"TIW HBBP Packer • N 16 _ m co0) ICC) CC) OND N LC) V V CNC) OMO r N LU N- O L() O M N CU 'C t p„ V N IN- M T QO a0 f— L!') N O O N V N CC) d- LC) N. 6) CC) w CU CO 6) O O O O N N N O N M M C) O N N O V M O O M 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O CO M M O) O C)) O O C) C)) 6) C)) 6) O CA M O CA 6) C)) C)) CA > F C2 O f' CU CO LD OO CC) N- N- CA N- N- 00 LU CA M N N- 00 M N- N- C)) t O N- O M r M LU r m CO Ch LU O LC) N- O - .4O OO N- N m C f� M N M M O V M cd 00 M M M - O N .4 O M LC) N- O CO co N- CA CD O O O O r r c- r 0 N N N -- M M M C0') CV O .4 .4 CA 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O CO CO CO CA C3) C3) Cn C3) CA CA Cn CA O O) C3) CA CA CA ) CA m ) H a) N N L• 0 0 0 0 N- CO .t LC) O Ln LC) M O O O CO CO O CO CO CO CD O O ++ Q N V' LC) L() O L() r LC) N crL() 00 co co V CO co N r 4 C N r O d M OO L() = O M O O O O O O O O O O O O O O O O O r r r r r N r r r r r r = = = = = = r = = = = = = • N 2 ✓ Q MN Q ' o p C r 0000 N- CO v LC) LC) LnUM000000COCD000000OCD O CD M N N I� N CO N O N L() r CO V d' N- co r , N- 0 CU o =M 0 I- M If) (C) CC) 1— CA O r r r N M N- OO CO CO CD O O O O CO CA W O M M O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M a 2 o w a 0 O 0 c .2 1.1.. <L N N N N N N N N N N N N a. li a Ll_ d a LL LL M W M toa. a. 000OOOOOOOOOa. a. a. a. a. a_ MMa_ MM m Q Q U) U) U) U) U) U) U) U) U) U) U) U) M Q M Q M M Q Q COM M 0. 0 t 0 N• LC) Lo M C'') m C') m C'') M C) M m C`') CY) C`') C`') C`') C'') C'') m m M C'') M M 0 0 0 0 0 0 0 0 0 0 0 0 0 0 000000000 NNNNN " NN " 00 CO CO CO CU CU CO CU CC) CC) c r r- N N N N N N N N N N N N N N r r r a— r r r r r CO CO Q_ O) CA CO M COCOCOCOCOCOCOCOCOCOCOCO 0 0 0 z < < < < < < < < < < < < < Q Q Q Q Q < < < < < < < N N N N N N N N N N N N N N N N N N N N N N N N N M M M M M M M M M M M M M M C'7 M M M M M M M M M M • • ❑ w 0 w ❑ ❑• ❑ w z LU w a p w 0 E— J w g g Y V O O O < Y Y cn u) 0 0 ww w J J J d d 0 0 < _ W W O O JJ O ❑ ❑ a w a 0 0 0 W z p Z w LU 0_ 2 2 2 O c i ccnn «a ca «a H O- d J i d = 2 O U) U) U) U) U) I- O Lu z Z u' 1 1 < L W O❑ Lu W 59J L ❑ w Z J U L W W LL W Q ❑ J H J J -J D a' a 0o 01DYw J J0Q 0 w w Q ¢ 2oamcn Li LI U_ v) a a W a cn OJ W N W Q Q m m u_ 0 0 a m • • �a_ O 0O Cr) I LLS F- O = N LQL °° 000 0 aO0 1- Li; H cnJ = UO0w H U o Q m Z rX < 0 ( 1 W O fX I-- • OJ D O O � nr � c00 N I" Q N N- Q U > ° U aD Q Z ZII W O M 7 Z = 1--- Q CN CN -) 2 rn odOOc~ooNO O W -I O C c o Z z II H w 2 N O W U Z = Q W 0 C `0 `0 630 >- o °- o < 0 LU as O >- N N co }- rQ W JO J D E RS Q .a) Q„ QZ coU) 00Z E m J U W 2 112 0 aoW - 0 >- oz < UQ U2oj � n D 42 �* CC QU) N � iao - - Oaa ( 0a W 7 • N cp- � dLo *, CL LO .5 QJ N V) 01 O U Z LL I v p c° aoUZW �0+ U) ° >(n o * * W H ao zoJ U) 2 D L COm d * cn * x W J H O O J N U) > H Z Oa LooaLo = � > > z � � rII ° w = D 7D7 - Mc R' DOW W HodH 2 I- 0. ••— rnQeNrn >� Q � QQEtHQLL� � a U) re u) 2 - 7 2 > W Q - H ry z = H W J A Q °' 0 0 oz NODZ W Qoo LJLI .- CU CU - O L } O LL W z a_ 0 J U -, Oct - 0 o > p f fYCtmCC1Y �., 0 D 00 0H � � DLu Q r (n (A Z U) U) N U) z I Uwz6 O N 12 O 0 0 H O 2 W W a W W o H H H J 0 J J J , H » U) » Ow = � z (° `\10 OW - II 2 wajz_ z_ r _zz_ � JU) Ooaori = JZ WO J H HZZ = H H O J J O W' Q 7 Ep • W H O0 OOw0* 0 - Etco4r 10OOzu_ QQ0 U Q * * C IIDHMW JZ a) * E2 * * * * o * * HU) U) CCQ it CC WLL * o W H Q �n o O Lo Lo >- 0 0 0 0 U, H N N N N - N 5 O ,- N m 0 rn Q • "aAD A'c�° -I-' G-3 2 A SNOTE: TTRD SIDETRACK COMPLETION * " ACTUATOR= AXELSON WELL ANGLE>70°@ 9459'"' OKB_ELEV= 72.3' I BE REV= 35.92' KOP= 4197 2089' —14-12"SSSV OTIS LANDNG NP,D=3.813" Max Angie= 95°@ 10184' Datum MD== 9269' Datum 1VD= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347" 1—I 2684' 9.5/8"CSG,47#,L-80,D=8.681" —I 4268' .------X ' ( 8396' —I4-12'OTIS XA SLD SLV,D=3.813" TOP OF 2-718"LNR H 8405' _ 8405' H4-1/2"X 2-7/8'PKRMGR W/TB3ACK,D=2.370" i Ill se mIM 8426' —TOC N 4-1/2"X 2-7/8"ANNULUS Minumum ID =2.37" @ 8405' ► 14 2-7/8" LINER TOP, PIN ID ;, j%. 8455' -ITIWSBRTBGSEAL ASSY .4•4VI ►� 04 01 8470' H9-5/8"X 4-1/2"TIW l- BP PKR,D=4.750" ►2'I —4 ►_i••.• ►'1'�v 8518' —14.1/2"OTIS X NP,D=3.813" TOP OF 7"LNR -I 8529" •�i i 0�4* BEHIND ► 41 i► 1• 8555' —14-12'MLLE)OTIS XN NP,D=3.8" CT LNR il 0A i'44 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" —I 8589' :V 0 8589' —I4-112'WLEG,D=3.958" ►•�• ► _ ... 9-5/8"CSG,47#,L-80,D=8.681" — .4 I 8779' , 1A ♦♦ 111TOP OF VIA IPSTOCK 9120' O•. ►♦•• ■ 7"LNR,26#,L-80,.0383 bpf,D=6.276" —9115 o*,,• ♦♦ j.� IT V 'A 7ovi IAA SIDETRACK WE/COW (G-32A)9115-9122' PERFORATION SUMMARY REF LOG:SPERRY SUN REND/GR ON 01/25/97 ANGLE AT TOP PERF:23°@ 8790' Note:Refer to Rod uction DB for historical pert data SIZE I SPF j 44TB?VAL I OPWSOZ( SHOT i SOZ SEE PAGE 2 FOR FERE SUIVMARY ' II I ? —IFISH•12"X 6"STFFENER RING(11/20/13) 11 11330' —I RSH-ASL&PUSH CBP(0&27/13) 2 11330' --I FISH-CEP A4LLED&PUSHED TO TD(08/20/13) 11330' —H2-7/8"CBP(01/18/09) 11f 12133' -I FISH-CEP AILED&PUSHED TO TD(07/12/03) PBTD --I 12125' 2-7/8"LNR,6.5#,L-80,.0058 bpf,D=2.441" —I 12220' tfillS DATE REV BY COM ENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/22/86 ORIGINAL COMPLETION 11/25/13 JRP/JMD ADF RFS&FISH(11/16-20/13) WELL: G-32A 02/20197 TTRD SIDETRACK COMPLETE 12/03/13 LD/JMD FERE SOZ CORRECTIONS(08/22/1 FERMf No: 1970010 07/12/03 TMtNiKK MILL/PUSH CEP TO TD 10/02/15 DHS/JMD ADPERFS(09/14/15) API No: 50-029-21636-01 07/14/03 CMDTTLP KB ELEVATION CORRECTION SEC 12,T11N,R13E,1922'SM..&4312'WEL 02/29106 CO/DTM FERE CORRECTION(6/13/04) 02/07/07 RLMYTLH PERM OFEN 7/12/03 BP Exploration(Alaska) • G-32A • i 1 14 • 4: ' 4 OM ter: 41/ PERFORATION SUMMARY * 4.R FO. REF LOG:SPERRY SUN MVVD/GR ON 01/25/97 IAA X41 ANGLE AT TOP PERF:23'@ 8790' t ►`�� Note:Refer to Production DB for historical perf data •• ##, SEE SEE SPF P.fTE RW VAL OPSQZ SHOT SQZ 4,4 141 2" 6 8790-8820 0 09/14/15 S 2" 6 8830-8840 0 09/14/15 ••. • 2" 6 9520-9550 S 07/29/10 08/22/13 A.� I 111 2" 6 9620-9650 S 07/29/10 08/22/13 ��• WM,/ 2" 6 9674-9704 S 07/29/10 08/22/13 • 1111 2" 6 9727-9757 S 07/29/10 08/22/13 �% ••. • 2" 6 9988-10018 S 07/29/10 08/22/13 ��� ►�1�1 2" 6 10024-10054 S 07/29/10 08/22/13 •4 ►�1�1 2" 6 10105-10140 S 01/18/09 08/22/13 ••• ►���� 2" 6 10145-10155 S 01/18/09 08/22/13 •4 /10). 2" 6 10380- 10680 S 01/26/01 08/22/13 • ' 1-11/16" 4 10740-10920 0 02120/97 2" 6 10740-10920 0 01/26/01 2" 6 10840-10870 0 11/18/13 2" 6 10870-10900 0 11/17/13 2" 6 10888-10918 0 11/16/13 1-11/16" 4 11010-11120 0 02/20/97 2" 6 11018-11048 0 11/16/13 2" 6 11048-11078 0 11/16/13 1-11/16" 4 11600-11910 02/20/97 1-11/16" 4 11960-12100 02/20/97 DATE REV BY COMRrENTS DATE REV BY CO LENTS PRIJDHOEBAY UI'IT 08/22/86 ORIGINAL COMPLETION 11/25/13 JRP/JMD ADFERFS&FISH(11/16-20/13) WELL: G-32A 02/20/97 TTRD SIDETRACK COMPLETE 12/03/13 LD/JMD PERE SQZ CORRECTIONS(08/2211 PERMT No: 1970010 07/12/03 TMWKK MLL/PUSH CEP TO TO 10/02/15 DHS/JMD ADPERFS(09/14/15) API No 50-029-21636-01 07/14/03 CMO/TLP KB ELEVATION CORRECTION SEC 12,T11N,R13E, 1922'SM..&4312'WEL 02/29/06 CO/DTM PERF CORRECTION(6/13/04) 02/07/07 RLMTLH PERFS OPEN 7/12/03 BP Exploration(Alaska) • STATE OF ALASKA RECEIVED AL .KA OIL AND GAS CONSERVATION COMM,__ION DEC 1 7 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon (J Repair Well ti Plug Perforations U Perforate U. Other LI : O(3 CC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other El 4 Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development 0 Exploratory ❑ 197-001-0 3.Address: P.O.Box 196612 Stratigraphic Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-21636-01-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028280 ' PBU G-32A• 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: Total Depth measured 12220 feet Plugs measured 11330 feet true vertical 9024.69 feet Junk measured See Attachment feet Effective Depth measured 11330 feet Packer measured See Attachment feet true vertical 9051.12 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface 2650 13-3/8"72#L-80 27-2677 27-2676.67 4930 2670 Intermediate None None None None None None Production 8746 9-5/8"47#L-80 26-8772 26-8420.51 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet �{ cc True Vertical depth See Attachment feet II UI JAN 1 3 Z U 14, Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 28-8581 28-8243.78 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10740'-10920',11010'-11120' Treatment descriptions including volumes used and final pressure: 52 Bbls 12%HCL,50 Bbls 9:1 Mud Acid,3456 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 370 30308 7 0 861 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El - Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil p . Gas LJ WDSPLIJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Gar .Catron • BP.Com Printed Name Garry Catron Title PDC PE Signature ,w✓. /jam. =;,w- Phone 564-4424 Date 12/16/2013 1 Gg 0, 4/7, DEC 2 0 20 il fili I- Form 10-404 R vi se d 10/2012 Sub mi t Original Onl y • G-32A 197-001-0 Junk Attachment SW Name MD Date Description G-32A 11329 8/20/2013 Milled CIBP G-32A 11329 8/28/2013 Milled CBP G-32A 11329 11/20/2013,1/2"x 6" Stiffenere Ring G-32A 12133 7/13/2003 Milled CIBP Packers and SSV's Attachment ADL0028280 SW Name Type MD ND Depscription G-32A PACKER 8412 8022.45 2-7/8"TIW S-6 Packer G-32A PACKER 8462 8068.98 4-1/2"TIW HBBP Packer • • am • co c) 00 N- Co N. o • ti oUn O 'cf * to N N- V co O NI' OQ M co CO• 1- N- CO •zr 000 CD 00 • N- 00 � CC) 00 Lt, CDCON- o N M � N CO Nr O N- O CO N CA CO 0000N00 c N- '— Lc, O O N 000000N N CCOONN ON- CO CO CO U) N N I� 00 N r- CA I- 00 O N r M CO CC) CD CO CO N 00 V CO CC 013 2 N CO CO O N CO CON- 00 aI (V N � 10N NN CO C Q C9 ■ Q O O O a) 0 0 00 00 a) Op 00 I J 0o J (n N * cNtD •N CO r V N (A � N 'o O ti to (V c7 N N O v— Nr V C co 00 •O ti CO in J M Ln co N co • Z O 0 w H > > w <LL V Z w w w m O Z Z J D D UJJLU) U) H Q O N Q 't O O N C N � � 3 D ° o � C° a) NE— � N co z a a) m (/) r °O * CO C CO C (n C CJ •N U) N 0 H vo v C H Q H co O 0 E _c U <n ca m U CO U C C U) UU) o - U) v L I CO C O - U) O I N o -0 _C O E •�U• C Q cD0 - Q a C = Q 0 Q Q cn 3 a CO CO -0 U 6 O 1,`O o o CO o m CO Qaa m lu < o a * Q LT Q ' a) [1: 70 L :-0 �X) 0 Q 0 O o L p N tCD U 0) ■U r N M O 5 1 N a) U r t -a U O •< r r < 0 a C N < r a o �Q 0_ b a) NQa- Q � a) co t < a) a) a) t < a) r .QQ �rx U) M /co r M U O M * E co � 0 U � �/ C L o .ri 0 a> — � O C� C L C Q C� C Q a * * * ° Q L 11. * 0 _ * ° Q L C * ° .` M * Cr) "C '� C CO O a) O M "C C .�M •tv L ,-, a) 3 T M U) > O z o > o Ln = a) > n o 7 0)N CD - = '_ r In C _ � Uo croQ — O C 4= ma0 C O 0 Y a) - I C a) Or X Or co CV 0 a) N ,- C a) X o - C r O Q ° i r ' Q C O r 0 2 r O N 0 CO ° = O ° a) ,- c) - 0 o = Or con cn `i 0 E C E 0) O O r E .) , co O ' E 0) ' co o E O -J a) c o O 2 a a) cm o a) o f a) — o o a o (n O L t 0 N- — — Q 4- N- 0 N a ,- N - (a ° N- .-- N- (N 06 a O Q (6 C O ' C Q. O a U) N O O +� a) O -0 4- O i U) p co 7 0 ,- O a) a) U O O N O C (� C r '6 C C ° C -o L C r M Co a) CO * M �1 (0 0 p '� M C 0 C C * M - C >4 N 0 2i 0 M N V LL L 0 to N D D 0 M N Li_ U (, M N� - * * i II a ' * (Q II rn J 0 * r * r CD �i O D 0 I I a a 0 U O *k C *k — Ur co = *k a) 0 E C2 1$ Uo � U U D U) -- (n a' = * - .0 = U) — to (6 }, U) o .0 � 3 o N E C M p � U c 3 p C a) C U D O D a) U co .°_ �o D 'E' '' U o v) a D ) U en cD a) a - r U _ to O - 0 0 ++ - a) +' +J 4.) 0- (A � r a) cV o tn0r to U) Cac0 Cl) = LC> N L (A C r a) () a) O r o L r U) ' r O o m 0 D m 0 m f- Q H co LO ..0 ' f- - CO (B .O .0 O E- CO ai 0 H N * M $ = O (X (d U) D O a= 0)(X M D _ ° m CC M I- -- (n2 (r) U) -f I— ,_= (n a) i— V) o (n . 1 — oD (/) ,'n 02 < 0 ‘-- < 0 00 + a r Q 0 ;k-. .EE -o < 0 0 E 92 G < V M co co co co co co co co r r r r r r r r r O O O O O O O O O N N N (NI N N N N N tf) to (0 CO N- N- co CO a) r r r r r r r r r r •- r r c- r r r r r r r r r r r r J CCCO Q ((0 C) (f Cl) O o 0 (o ) >i Eh • O a) > •U L - 0 a) - O N N O a) O co 0) a) N 0) O E d m ON LL C 7 ,- co l0 N o C OL ' — C (o O >,7 o E .s p xO— O� U Uc E UY C o• � -0 3 0._ Q -0 0 - a) - in in _0 ° i A = 7 A A y N a) A 7_ 0 m 2 N � � k 2c U 2 * / 2 � 7 ¥ _ ¥ o O / / 4 / 0 co _ \ 3 E c 5 2 2 / \ E / 2 \ g / / ƒ ® CO .4-_,- 6 k / t 0/ / / k 4 0 * . / f f 2 & ® g 3 & c = m - $ y S \ E 7 / / = S / / Li 0 ® S / \ OD / / / -) / / - \ & ± 2 R ± \ ± ✓ 5 .0 4 w - c v w 9 _ 2 ✓ a .0 c E \ \ v \ < f < Cl) -0 i_ cm \ § N N • G E - c . co § 0 0 = a a 5 ƒ % f a) ƒ / / < b % * .k § G e < \ / % m \ \ / \ / r I t P _ Q % E22 / / / I / � / O co / f /� ? Q \ . N- % CD CO £ c 2 a U \ ( t e. \ ± 3 2 R 0 .- f / / 2 / % o / § Cl) 0 ii R 2 ii a c hi ' CD / E (') � / 0 / / E $ o O < S » n ® / --5 / a 0 / / \ / CO • _ 0) (13 R \_ 0 G R2 R / J / / C \ / - -) / � o - * o 0 ' - o \ 0 a) > c p% \ o � g ¥ 7 ® UI 2 —' co / A E o. e ° - A = - g - _/ 0.) 0 7 t \ 9 I § - \ / \ 0 I- O o / G2z 5 w .- _ < + U c .%\ § 2 // ' © 0 / / / / /0\ a n = c e 2 « / o o / k � / U__ N \ 2 ƒ / ƒ ƒ / 0 ± • . R - co = c R 2 c R $ # .R 6 U E y U t # R - U t m U * D c r G 2 / o 1 0 D c 0 L 2 t $ R o a o 2 m - G o _) m - r g - U 0 c 5 2 e « < a U U t < » .- < 3 co co / co co 0 0 0 0 0 ® 9 9 N N N to co / \/ 1 .IF&1±.= 4"aW WELLHEAD= McEVOY G-32A SA r NOTE: TTRD SIDETRACK COMPLETION ACTUATOR= AJ(I3SON WELL ANGLE>70°@ 9459' OKB.ae/= 72.3' I 1 BF.H.EV= 35.97 KOP= 4197 I 2089' —14-1/2"SSSV OTIS LA NONE NP,D=3.813" Max Angle= 95°@10184' Datum MD= 9269' Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347" H 2684' 9-5/8"CSG,47#,L-80,ID=8.681" H 4268' f------X X ' ' 1 8396' —{4-1/2'OTIS XA SLD SLV,D=3.813" TOP OF 2-718"LNR — 8405' 8405' 4-1/2"X 2-7/8'FKR/HGR W/TEBACK,D=2.370" F! A 8426' —1TOC IN 4-1/2"X 2-7/8"AULUS Minumum ID =2.37" @ 8405' ► 14 NV •2-7/8" LINER TOP, PIN ID ,►� gra, 8455' -jTNVSBR TBG SEAL ASSY ° VI -�11 `'�.' 8470' —19-5/8"X 4-1/2"TM/HBBP PKR,D=4.750" Ie.Q ►4:1.1 ♦ . 8518' H4-1/2"OTIS X NP,D=3.813" TOP OF 7"LNR—I 8529' '�►•• 1 0 ( '14 BEHIND ♦ A411 ■,0 1.1 8555' H4-1/2"NI-LED OTIS XN NIP,D=3.8" CT LNR AA 144 4-1/2"TBG,12.6#,L-80,.0152 bpf,ID=3.958" H 8589' /'emu 1140 8589` -{4-1/2"WLEG,D=3.958" M ►1111 9-5/8"CSG,47#,L-80,ID=8.681" — 8779' i�i� ►111. I ■ 1,4•. ►1i ♦♦ N. TOP OF WHIPSTOCK -( 9120' ►iii ►1111 7"LNR,26#,L-80,.0383 bpf,ID=6.276" H —9115 *�i ■►44' Vj 1•1 ►♦•� 1144 PERFORATION SUMMARY °��4 ■1111• REF LOG SPERRY SUN MIMYGR ON 01/25/97 ►iii 11111 W 11111 ANGLE AT TOP PERF:86°@ 10740' W W. Note:Refer to Production DB for historical pert data °A I1�1�•SIZE SPF INTERVAL OPWSOZ SHOT SQZ ,M SIDETRACK WINDOW (G-32A)9115-9122' 2" 6 9520-9550 S 07/29/10 08/22/13 2" 6 9620-9650 S 07/29/10 08/22/13 2' 6 9674-9704 S 07/29/10 08/22/13 2" 6 9727-9757 S 07/29/10 08/22/13 2" 6 9988-10018 S 07/29/10 08/22/13 2" 6 10024-10054 S 07/29/10 08/22/13 2" 6 10105-10140 S 01/18/09 08/22/13 2" 6 10145-10155 S 01/18/09 08/22/13 I 2" 6 10380-10680 S 01/26/01 08/22/13 1-11/16" 4 10740-10920 0 02/20/97 2' 6 10740-10920 0 01/26/01 t ? --{FISH-1/2"X 6"STFFENER RING(11/20/13) 2" 6 10840-10870 0 11/18/13 2" 6 10870-10900 0 11/17/13 I' 11330' H FISH-MLL&RUSH CBP(08/27/13) 2" 6 10888- 10918 0 11/16/13 iii 11330' —{FISH-CBP MLLED&PUSHED TO TD(08/20/13) 1-11/16" 4 11010-11120 0 02/20/97 2" 6 11018 11048 0 11/16/13 11330' -12-7/8"COP(01/18/09) 2' 6 11048-11078 0 11/16/13 12133' —I FISH-CEP MLLED&PUSHED TO TD(07/12/03) 1-11/16" 4 11600- 11910 e: 02/20/97 1-11/16" 4 11960-12100 Y; 02/20197 #, PBTD H 12125' 2-7/8"LNR,6.5#,L-80,.0058 bpf,ID=2-441" 12220' DATE REV BY COMMENTS DATE REV BY COMETS PRUDHOE BAY UNT 08/22/86 ORIGINAL COMPLETION 11/25/13 JRFIJMD ADFERFS&FISH(11/16-20/13) WELL: G-32A 02/20/97 TTRD SIDETRACK COMPLETE 12/03/13 LLYJMD PEE SQZ CORRECTIONS(08/22/1 FFRMT No:'1970010 07/12/03 TMN/KK MILL/PUSH CBP TO TD API No: 50-029-21636-01 07/14/03 CMO/TLP KB ELEVATION CORRECTION SEC 12,T11N,R13E, 1922'SNL&4312'WEL 02/29/06 CO/DIM PERE CORRECTION(6/13/04) 02/07/07 RLMrTLH PERFS OFBV 7/12/03 BP Exploration(Alaska) , RECEIVED STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COMMISSION SEP 1 8 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCCi 1.Operations Abandon Li Repair Well Li Plug Perforations L Perforate U Other Ld Mill CIBP Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Weil❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development ig Exploratory ❑ 197-001-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-21636-01-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028280 PBU G-32A . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 12220 feet Plugs measured 11330 feet true vertical 9024.69 feet Junk measured See Attachment feet Effective Depth measured 11330 feet Packer measured See Attachment feet true vertical 9051.12 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface 2650 13-3/8"72#L-80 27-2677 27-2676.67 4930 2670 Intermediate None None None None None None Production 8746 9-5/8"47#L-80 26-8772 26-8420.51 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet SCANNED NOV 1 4 2013 True Vertical depth See Attachment feet n Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 28-8581 28-8243.78 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9520'-9550',9620'-9650',9674'-9704',9727'-9757',9988'-10018',10024'-10054',10105'-10140', 10145'-10185',10213'- 10233',10380'-10680',10740'-10920',11010'-11120'(Acid) 9520'-9550',9620'-9650',9674'-9704',9727'-9757',9988'-10018', 10024'-10054'(Cement Squeeze) Treatment descriptions including volumes used and final pressure: 24 bbls 12%HCL; 150 bbls Organo Seal,25 bbls SqueezeCrete Cement,2891 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 370 30308 7 0 861 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorA0 Development El • Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil S . Gas Li WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUdJ 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.Cati-cg L,BP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date 9/18/2013 RBDMS SEP 2 0 2 v F- /b //°1 /3 / Form 10-404 Revised 10/2012 i.' L tf p Submit Original Only Casing / Tubing Attachment ADL0028280 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 28 - 108 28 - ' 108 1490 470 LINER 3815 2-7/8"6.5# L-80 8405 - 12220 8080.07 - 9024.69 10570 11160 LINER 594 7"26# L-80 8521 - 9115 8188.01 - 8732.88 7240 5410 PRODUCTION 8746 9-5/8"47#L-80 ' 26 - 8772 26 - 8420.51 6870 4760 SURFACE 2650 13-3/8"72# L-80 27 - 2677 27 - 2676.67 4930 2670 TUBING 8553 4-1/2" 12.6#L-80 28 - 8581 28 - 8243.78 8430 7500 • • • • G-32A 197-001-0 Junk Attachment SW Name MD _ Date Description G-32A 11329 8/20/2013 Milled CIBP G-32A 11329 8/28/2013 Milled CBP G-32A 12133 7/13/2003 Milled CIBP it • • Packers and SSV's Attachment ADL0028280 SW Name Type MD ND Depscription G-32A PACKER 8412 8086.59 2-7/8"TIW S-6 Packer G-32A PACKER 8462 8133.12 4-1/2"TIW HBBP Packer Perforation Attachment ADL0028280 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base G-32A 8/22/2013 SQZ 9520 9550 8992.05 8997.54 G-32A 8/22/2013 SQZ 9620 9650 9003.38 9003.68 G-32A 8/22/2013 SQZ 9674 9704 9003.16 9001.82 G-32A 8/22/2013 SQZ 9727 9757 9000.37 8998.2 G-32A 8/22/2013 SQZ 9988 10018 9004.57 9007.55 G-32A 8/22/2013 SQZ 10024 10054 9008.19 9011.48 G-32A 8/26/2013 BPP 10105 10125 9016.97 9018.41 • G-32A 8/26/2013 BPP 10125 10140 9018.41 9018.62 G-32A 8/26/2013 BPP 10145 10155 9018.47 9017.88 G-32A 8/26/2013 BPP 10155 10185 9017.88 9015.49 G-32A 8/26/2013 BPP 10213 10233 9013.3 9012.15 G-32A 8/26/2013 BPP 10380 10680 9003.55 9010.25 G-32A 8/26/2013 BPP 10740 10920 9014.09 9026.55 G-32A 8/26/2013 BPP 11010 11120 9033.48 9040.3 G-32A 8/26/2013 BPP 11600 11910 9040.2 9029.69 G-32A 8/26/2013 BPP 11960 12100 9028.99 9026.45 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN • SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Daily Report of Well Operations ADL0028280 ACTIVITYDATE SUMMARY Rig up, function test BOP's. RIH w/ BHA; 1.9" ctc, 1.7" dfcv, 1.69"jars, disco, circ sub, motor, 2.3" 5 blade junk mill (oal= 19.18') Tag top CIBP at 10093'. correct depth to 10090. Start milling top CIBP. Milled & Pushed Cl BP tagged down at 11330', pickup for wt back flagged ct pipe electronic 11322.5' mechanical 11325'. POOH with motor& mill. 8/20/2013 **job continued on WSR 08-21-2013** • ***Job Continued from WSR 08-20-2013***CTU 8 w/ 1.75" CT. Scope; GSO w/OrganoSEAL and SqueezeCRETE. RIH MU CTC 1.90", dbpv 1.70", disco 1.69" , xover 1.69", stinger 1.75", stinger 1.75", JSN 1.75" (AOL 11.4'). PJSM discuss pump procedures of HCL. IA 1136 psi OA 12 psi. Pump 51 bbls KCL 1.4 bbls/min WH 300 psi injectivity. Pump 24 bbls of 12% HCL. reciprocate over the interval 9520'- 11120'. Pump 2% kcl to over displacement 50 bbls down CT. 250 bbls. down ctbs while pooh. RIH w/ BHA; 1.9"ctc, 1.7" dfcv, 1.69" disco, 1.47" crossover, 1.69" inflation valve, 1.72" setting tool, 2.1" adapter, 2.1"composite plug (oal=17.21') Tag CIBP at 11330'. no correction was necessary. PUH to 10700. Set BOT 211 Direct Shear Composite Bridge Plug. Stack 4k DW on plug and pickup clean. pooh. recovered ball. Perform injectivity test 1 bpm @ 26 psi/2 bpm @ 346 psi/3 bpm @ 730 psi/4 bpm @ 1058 psi. Pump 150 bbls organo seal down CTBS followed with 15 bbls water and 94 bbls of diesel. RIH w/ BHA; 1.75" ctc, two 1.75" stingers, 1.75" JSN (oal= 7.95'). Jet fresh water thru liner to plug at 10700' PUH to 8400'. Bullhead cement**job continued onWSR 08-23-2013** 8/21/2013 • Continued from WSR 08-21-13 CTU 8 w/ 1.75" CT. Scope; GSO w/OrganoSEAL and SqueezeCRETE. Bullhead cement. Bump and hold squeeze pressure 500 psi increments for 15 min. Called town APE discussed squeeze pressure. Hold for 30 min. 3000 psi for 30 minutes, then start clean out.for final squeeze pressure. Final squeeze pressure was 2891 psi after 30 minutes. Estimate 7.9 bbls behind pipe. Slowly bleed WH psi down to 300 psi. Drop ball 5/8" ball pumping powervis. RBIH clean out cement down to 10700' CBP, lay in clean powervis from 10700' to 9300'. POOH. Freeze protect tubing 58 bbls. At surface close swab holding 300 psi on WH.Final IA 1413 psi OA 24 psi. RDMOL. 8/22/2013 ***Job complete*** Daily Report of Well Operations ADL0028280 T/I/O= temp= S/I Pressure test TBG to 1000 psi (Profile Mod) Pressured up TBG to 1000 psi against cement plug with 1.09 bbls 50*diesel. tbg psi lost 68 psi in 15 min pressure test. called in results to fullbore, Good PT Final WHP's 10/600/0 SV,WV=closed, MV,SSV,IA,OA=open All 8/24/2013 hadrline valves closed, tag hung CTU 8 w/ 1.75" CT. Scope; Mill out cement&CBP. N2 lift for kickoff: RIH w/Baker BHA MU Baker BHA CTC 1.75", DBPV 1.69", Jar 1.69", Dsico 1.69", DCV 1.69, Tempress 1.69", Tempress Hydro Pu111.69", Motor 1.69", Pirahna Mill 2.29" (OAL 21.19). Hold WH psi 1000 psi for 30 minutes, pressure bled down to 988 psi 12 psi loss. RIHTag CBP 10,694.4' begin milling. Milled/Pushed CBP down to 10,786' CTM. POOH to check mill, not making much progress. • LD mill and motor. Mill had CBP and cement on face. MU 5 blade mill and motor. RIH. Mill ahead from 10788' at 60 fph with 100-200 psi motor work. Mill to 10811' 8/26/2013 ***Job in progress*** CTU 8 w/ 1.75" CT. Scope; Mill out cement& CBP. N2 lift for kickoff: Mill ahead from 10811'. Mill cement to 11010'. Wiper trip above TOL to 8000'. Mill cement from 11010' to 11,118"At 11,118' started moving down hole with no problems or seeing motor work Pushed down to 11,320'. Pump gel sweep 10 bbls from 11,300" PUH chase out gel for bottoms up. Town APE wants injectivety test perfomed after CBP & cement was milled up. Perfomed Injectivity test at .3bbls/min 1550 psi, .5 bbls/min 1760 psi, .7 bbls/min 2004 psi, 1 bbl/min 2220 psi, 1.5 bbls/min 2400 psi, 1.7 bbls/min 2427 psi., 2 bbls/min 2570 psi. Perfomed another injectivety 1 bbl/min 2020 psi. Town APE called and wants to go ahead with the N2 lift. RIH pumping N2 at 500 scfm. Park at 7025' (6800' TVD) and lift. Well unloaded and then fluid rate stopped. Shut down N2 and wait for well to load up. 8/27/2013 ***Job in progress*** CTU 8 w/ 1.75" CT. Scope; Mill out cement& CBP. N2 lift for kickoff: Wait at 6997' for well to build up. Lift with 500sfcm N2 from 6997', well blew dry. SI and let well load • up. N2 rate= 500 scfm Flowline 40 deg F. PCC rates 0 BFPD, 2 mmscfd. Offline with N2 build another slug. PCC rates 0 BFPD, 1.67 mmscrd. Called Town APE, discussed N2 lift. well not coming on, decision to rig down N2. Freeze protect tubing 38 bbls Meoh. POOH . Perform BOP/ EVACUATION DRILL RDMOL 8/28/2013 ***Job complete*** ■ WaLI- 4'CFVV G-32A W[iLHEAD= AkEVOY S*** NOTE: TTRD SIDETRACK COMPLETION AC UATOR= AXE_SON WELL ANGLE>70 @ 9459 KB.ELEV= 64.1' I - - I BF.ELEV= 35.92' KOP= 4197 I 2089' H4-11T SSSV OTIS LANCING NP,D=3.813" I I x Angle= 15 at 10184' Datum ID= 9269' Datum 7VD= 8800'SS 113-3/8"CSG,72#,L-80,D=12.347' H 2684' 9-5/8"CSG,47#,L-80,D=8.681" --I 4268' 1,------>( ' ( I 8396' I-14-1/2"OTIS X/1 SLD SLV,D=3.813" I TOP OF 2-7/8"LNR —I 8405' I e ►�� 8405' 14-112"X 2-7/8'R(RIHGR W/T�ACK,D=2.370" • ■ 8426' HTOC N 4-1/2"X 2-7/8"ANNULUS I Minumum ID =2.37" @ 8405' 1 VI 2-7/8" LINER TOP, PIN ID ;; ►�i, 8455' H11WSBRTBG SEAL ASSY A r4 ►i (4t 8470' H9-5/8"X 4-1/2"ITW HBBP PKR,D=4.750" •,►� ••� 1''4•x; 8518' —14-1/2"OTIS X PP,D=3.813" I BEHIND TOP OF 7"LNR—{ 8529' 'i• *14. ►;�! •I 1' 8555' H4-1/2"MLLE)OTIS XN NP,D=3.8' CT LNR ••►� 14t 4/' 4-1/T TBG,12.6#,L-80,.0152 bpf,D=3.958" -I 8589' ∎,,_•i /44• 8589' 1--I 41/2'WLBS,D=3.958" ►:•1 14441 • 141 •ii 14441 9-5/8"CSG,47#,L-80,D=8.681" --I 8779' I—A ►iii 14141 %% 1L A. 14441 ITOP OF WHFf'STOCK H 9120' ►�4. W. 7'LNR,26#,L-80,.0383 bpf,D=6.276' --I —9115 '••• +4444 PERFORATION StaJAPRI' m 14.,4• REF LOG:SFERRY SUN MMYGR ON 01/25/97 � '' SIDETRACK WINDOW (G-32A)9115'-9122' ANGLE AT TOP PERF:85°@ 10105' ' ' Note:Refer to Production DB for historical pert data SIZE SPF t41 lAL OPWSQZ SHOT SOZ ' 2" 6 9520-9550 0 07/29/10 2" 6 9620-9650 0 07/29/10 ' 2" 6 9674-9704 0 07/29/10 2" 6 9727-9757 0 07/29/10 2" 6 9988-10018 0 07/29/10 ' 2" 6 10105-10140 0 01/18/09 2" 6 10024-10054 0 07/29/10 T ' 6 10145-10155 0 01/18/09 T 6 10380-10680 0 01/26/01 11330' --I FISH-MLL&PUSH CBP(08127/13) 1-11/16" 4 10740-10920 0 02/20/97 T 6 10740-10920 0 01/26/01 11330' —I FISH-CEP MLLED&PUSHED TO TD(08l20I13) I 1-11/16' 4 11010-11120 0 02/20/97 11330' 1-12-7/8"CBP(01/18/09) 1-11/16" 4 11600-11910 C 02/20/97 1-11/16' 4 11960-12100 a 02/20/97 ' 12133' —I FISH-CBP WILLED 8 PUSHED TO TD(07!12!03) 2-7/8"LNR,6.51,L-80,.0058 bpf,D=2.441" —I 12220' ∎1y 'B I H 12125' DATE REV BY COMtA NTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 08122/86 ORIGINAL COMPLETION 04/12/09 DMS/SV SET CBP/ADPERF(01/18/09) WELL: G-32A 02'20/97 TTRD SIDETRACK COMPLETE 03101/11 PJC CEP/ADPEiiF(07/29/10) FERMT No:'1970010 07/12/03 TMWKK &.LJPl1SH CBPTO TD 09/01/13 JGUPJC PUSH/SET CFBP(08!20-21/13) AR No: 50-029-21636-01 07/14/03 C3MD/TLP KB ELEVATION CORRECTION 09/02/13 JGUPJC MN-UPl1SH CBP BTM(08/27/13) SEC 12,T11 N,R13E,1922 SNL&4317 WEL 02/29/06 CO/DTM PERF CORRECTION(6/13/04) 02/07/07 RLM/TLH PBFS OPEN 7/12/03 BP Exploration(Alaska) S • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 May 18, 2012 &AMAAUG 0 7 2012 Mr. Jim Regg ©� I Alaska Oil and Gas Conservation Commission ri- 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB G -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad G 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, p� 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) G-Pad Date: 03/05/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal G -01A 1931710 50029202140100 3.0 NA 3.0 NA 10.2 5/10/2010 G -02B 2081580 50029202170200 0.5 NA 0.5 NA 2.6 5/10/2010 G -03A 1970700 50029202210100 0.7 NA 0.7 NA 6.0 5/27/2010 G-04B 2061400 50029202250200 0.1 NA 0.1 NA 1.7 5/10/2010 G -05 1780970 50029203510000 0.0 NA 0.0 NA 0.0 5/10/2010 G -06A 2060120 50029203580100 0.6 NA 0.6 NA 5.1 5/12/2010 G -07 1790180 50029203590000 0.5 NA 0.5 NA 3.4 5/11/2010 G -08A 2061830 50029205810100 0.1 NA 0.1 NA 0.9 5/27/2010 G -098 2071100 50029205820200 9.0 NA 9.0 NA 69.7 5/20/2010 G -10C 2060090 50029205530300 0.9 NA 0.9 NA 8.5 3/5/2012 G-11B 2080270 50029205830200 0.0 NA 0.0 NA 0.0 5/21/2010 G -12B 2031410 50029205970200 0.5 NA 0.5 NA 2.6 5/13/2010 G -13A 2001630 50029206000100 0.0 NA 0.0 NA Trace 5/12/2010 G -14B 2090680 50029206460200 0.7 NA 0.7 NA 5.1 5/22/2010 G -15B 2080650 50029206470200 26.0 4.0 0.5 7/16/2011 3.4 7/19/2011 G -16A 2090560 50029206430100 0.0 NA 0.0 NA Trace 5/22/2010 G -17A 2060760 50029206190100 21.4 4.0 0.6 7/16/2011 3.4 7/19/2011 G -18A 1990320 50029206200100 71.7 14.0 1.0 7/16/2011 8.5 7/19/2011 G -19B 2071240 50029215990200 0.0 NA 0.0 NA Trace 5/22/2010 G -21 1951540 50029226040000 0.5 NA 0.5 NA 3.4 5/12/2010 G -238 2091440 50029216800200 0.5 NA 0.5 NA 4.3 5/11/2010 G -24A 2060820 50029216710100 0.1 NA 0.1 NA 0.9 5/11/2010 G -25B 2070860 50029216520200 5.3 NA 5.3 NA 23.8 5/28/2010 G -26B 2050480 50029216610200 2.0 NA 2.0 NA 6.8 5/11/2010 G -27A 2070310 50029216460100 0.5 NA 0.5 NA 2.6 5/30/2010 G -29B 2101410 50029216500200 2.8 NA 3.0 NA 17.0 5/13/2010 G -30C 2091510 50029216130300 1.0 NA 1.1 NA 5.1 5/30/2010 G -318 2090310 50029216160200 0.8 NA _ 0.8 NA 6.0 5/21/2010 „Ai? G -32A 1970010 50029216360100 0.8 NA 0.8 NA 3.4 5/21/2010 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ^ Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory ^ ~ 197-0010 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 ~ 50-029-21636-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number ADLO-028280 PBU G-32A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12220 feet Plugs (measured) 11330 12133 feet true vertical 9024.69 feet Junk (measured) None feet Effective Depth measured 12133 feet Packer (measured) 8405 8470 true vertical 9026 feet (true vertical) 8080 8141 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 27 - 107 27 - 107 1490 470 Surface 2650 13-3/8" 72# L-80 26 - 2676 26 - 2676 5380 2670 Intermediate Production 8746 9-5/8" 47# L-80 25 - 8771 25 -8420 6870 4760 Liner 594 7" 26# L-80 8521 - 9115 8188 - 8733 7240 5410 Liner 3815 2-7/8" 6.5# L-80 8405 - 12220 25 -8420 6870 4760 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ - Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 20 - 8581 20 - 8251 Packers and SSSV (type, measured and true vertical depth) 2-7/8" Top Packer 8405 8080 4-1/2" TIW HBBP-R Packer 8470 8141 ~~~~~Q 12. Stimulation or cement squeeze summary: ~ "~ ~ ., Intervals treated (measured): :~ a~:s~1'~t d ~. (j R, u '. l ~I~~ska ~ Gay ~~~, ~~d17fYlisi~l7 Treatment descriptions including volumes used and final pressure: ~',t0i;')~7fir' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing .pressure Prior to well operation: 546 24875 7 757 Subsequent to operation: 14. Attachments: 15. Well Class after work: `~ Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature ~ Phone 564-4944 Date 8/2/2010 - ~ g ~~~~ G-32A 197-001 PFRF OTTOrHMFNT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base G-32A 2/20/97 PER 10,740. 10,920. 9,014.09 9,026.55 G-32A 2/20/97 PER 11,010. 11,120. 9,033.48 9,040.3 G-32A 2/20/97 PER 11,600. 11,910. 9,040.2 9,029.69 G-32A 2/20/97 PER 11,960. 12,100. 9,028.99 9,026.45 G-32A 1/25/01 BPS 11,350. 11,360. 9,051.34 9,051.25 G-32A 1/26/01 APF 10,380. 10,680. 9,003.55 9,010.25 G-32A 1/26/01 APF 10,740. 10,920. 9,014.09 9,026.55 G-32A 7/12/03 BPP 11,350. 11,360. 9,051.34 9,051.25 G-32A 1/18/09 BPS 11,330. 11,600. 9,051.12 9,040.2 G-32A 1/19/09 APF 10,213. 10,233. 9,013.3 9,012.15 G-32A 1/19/09 APF 10,155. 10,185. 9,017.88 9,015.49 G-32A 1/20/09 APF .10,105. 10,125. 9,016.97 9,018.41 G-32A 1/20/09 APF 10,125. 10,140. 9,018.41 9,018.62 G-32A 1/20/09 APF 10,145. 10,155. 9,018.47 9,017.88 G-32A 7/29/10 APF 9,520. 9,550. 8,992.05 8,997.54 G-32A 7/29/10 APF 9,620. 9,650. 9,003.38 9,003.68 G-32A 7/29/10 APF 9,674. 9,704. 9,003.16 9,001.82 G-32A 7/29/10 APF 9,727. 9,757. 9,000.37 8,998.2 G-32A 7/28/10 APF 9,988. 10,018. 9,004.57 9,007.55 G-32A 7/28/10 APF 10,024. 10,054. 9,008.19 9,011.48 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ~~ G-32A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 7/26/2010 MOL from 15-36, Test double stack valves, M/U & stab lubricator w/ 1.9"x 0.125' , CTC, 1.75" x 1.08' DFC, 2 stingers 1.75" x 9.33', & 2.25"x .58 JSN. BHA TOL ' I 11.12'. RIH for Drift run. ******'`**(CONTINUED ON 7-27-10)**"****"" i 7/27/2010=*******Continued from 7-26-10*"*""''*"'` RIH & tag CIBP w/2.25 drift assembly, @ I 11337, POOH. M/U BOT MHA & SWS logging tools. RIH w/logging tools for GR, CCL, &CNL pass. Kill well w/ 1.5X ann vol of KCL. Log 2 CNL passes from ;11336'-8300'. Log coil flag from 10400'-9400' w/flag @ 10030'. Field GOC pick ~ 3is unchanged from 2005 @ 9450' MD. MU/RIH w/ HES 2 7/8" CIBP. Correct j jdepth at flag.10,016.64'. Correlate CIBP to 10,090', Hal tool flooded out, POOH. ~ *"*****Continued on 7-28-10""***""* 7/28/2010`****"**Continued from 7-27-10****""*'"**RIH & Set WFD 2 7/8" liner plug a~ ~ `10090', POOH. Add lubricator for 30' TCP guns. MU/RIH w/Gun #1, 30' of 2" ,.Sh~ oot interval 10024'-10054'. POOH. MU/RIH w/Gun #2, 30' of 2" 6 spf guns, ;shoot interval from 9988'-10018'. POOH Cut 100' pipe, chain inspection, weekly ;BOP test. Cut 100' CT, install new CTC, pull & pressure test, 13K & 3500 psi. ?"""*"JOB NOT COMPLETE CONTINUED 7-29-10"**** 7/29/20103 Continued from 7-28-10 M/U 3rd set of 30 x 2 guns. RIH, Shoot 6 spf from 9727'-9757', POOH. M/U 4th set of 30' x2" guns, RIH, Tag CIBP for tie in `depth,.shoot interval 9674-9704~ooh, /U 5th set of 30' x 2" guns, RIH, Tag CIBP for tie in depth, shoot interval 9620-9650' 6 shots per foot, pooh, M/U 6th ~ set of 30' x2" guns, RIH, shoot last perf set from 9520'-9550'~v /2" x 30' x 6 spf.guns, POOH. M/U new CTC & BHA, 1.9" x 0.125" CTC, 1.75" x 1.08' DFC, ;1.75" x 4.58 'Stinger, 2.0" x 0.5"JSN. TOL 6.285'. Lay down 26' of lubricator. ___ ********Job Incom lete, continued 7-30-10""**"*'`*5 ~~_ ___ ____ W ~~~ ~~7/30/2010 "****Continued from 7-29-10*"**"" R/U WFD N2 Membrane unit, PJSM w/WFD E N2 & CT-9 crew, discuss operations, pressure testing, various safety & ;environmental issues. Blow down reel. RIH for N2 lift. Lift @ 200-600 scf/m to 39400'. **""*JOB CONTINUED ON 7-31-10***"* ~ 7/31/2010'***"**Continued from 7-30-10****""* N2 lift down CT parked @ 8350'. N2 off line. Oil & Gas rates are nearly the same (450 BPD & 30 mmscf) as before the CIBP =isolation & AD Perf job. Perform Emergency Drill. Job complete, RDMO, left ;well flowing to production. ! FLUIDS PUMPED BBLS 10 50/50 METH 962 1 %KCL SLICK 972 Total TREE = K • 4„ CNV WELIHEAD= McEVOY ACTUATOR = AXELSON KB. EIEV = 64.1' BF. EIEV = 35.92' KOP = 4192' Max Angle - 95 @ 10184' Datum MD = 9269' Datum TVD = 8800' SS ~ G-32A 13-3/8" CSG, 72#, L-80, ID = 12.347" I--I 2684• 9-518" CSG, 47#, L-80, ID = 8.681" 4268' TOP OF 9-5/$" CSG 4268' TOP OF 2-7/8" LNR ~-( s405, Minumum ID = 2.37" @ 8405' 2-718" LINER TOP, PIN ID TOP OF 7" LNR I-I 8529' 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ( 8589' 9-5/8" CSG, 47#, L-80, ID = 8.681" 8779' PERFORATION SUMMARY REF LOG: SPERRY SUN MWDIGR ON 01/25/97 ANGLE AT TOP PERF: 85° @ 10105' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OPN/SOZ DATE 2" 6 10105 - 10140 O 01/18/09 2" 6 10145 - 10155 O 01/18/09 2" 6 10380 - 10680 0 01/26/01 1-11/16" 4 10740 - 10920 O 02!20/97 2" 6 10740 - 10920 O 01/26/01 1-11/16" 4 11010 - 11120 O 02/20(97 1-11/16" 4 11600- 11910 C 02/20/97 1-11!16" 4 11960 - 12100 G 02/20/97 TOP OF WHIPSTOCK ~-j 9120, 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276° 9115' S E: TTRD SIDETRACK COMPLETION. HORIZONTAL WELL - 70° @ 9459' AND 90° @ 9646' 2089' 4-1/2" SSSV OTIS LNDNG NIP, ID = 3.813" I 4-112" OTIS XA SLIDING SLV, ID = 3.813" ( ${ 405, I--14-1/2" X 2-7/8' PKR/HGR W/TIEBACK, ID = 2.370" ( 8426' TOC IN 4-1/2" X 2-7/8"ANNULUS $455' TNV SBR TBG SEAL ASSY 8470' 9-518" X 4-1/2" TM/ HBBP PKR, ID = 4.750" 8518' 4-1/2" OTIS X NIP, ID = 3.813" 8555' 4-1/2" MILLED OTIS XN NIP, ID = 3.8" $5$9' 4-112" TBG TAIL ELMD TT NOT LOGG~ SIDETRACK WINDOW 9115' - 9122' p ~1 ~ J 11330' 2-7i8° CIBP (01/18/09} 12133' GIBP-MILLED & PUSHED TO TD (07/12/03) PBTD H 12125' I 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID = 2.441" I DATE REV BY COMMENTS DATE REV BY COMMENTS 08!22/86 ORIGINAL COMPLETION 04(12/09 DMS/SV SET CIBP/ADPERF (01/18/09) 02/20/97 TTRD SIDETRACK COMPLETE 07/12/03 TMN/KK MILUPUSH CIBP TO TD 07/14/03 CMOlItP KB ELEVATION CORRECTION 02/29/06 CO/DTM PERF CORRECTION (6/13!04) 02/07/07 RLM/TLH PERFS OPEN 7/12/03 PRUDHOE BAY UNIT WELL: G-32A PERMIT No: 1970010 API No: 50-029-21636-01 SEC 12, T11N, R13E, 1922' SNL & 4312' WEL BP Exploration (Alaska) V /f~~L~ ~~,d~T ~1~~4Na~/1~~4L BroActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/C?pen Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska, Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and 1 ~4~/U ProActive Diagnostic Services, Inc. Attn: Rabert A. Richey 130 West Internat~nal Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245.8952 1) Coif Flag 19~Jan-09 G32A 2j Jewelry Log 19,Jan-09 G32A `~ Signed Print Name: E~ 50-029-21636-01 EDE 1 Date : '~~~~ ~~~ ~~. _ iii ~ -t~s. ~~aa~~~~i ~,,~h PRO/icTNE Du-c;NOSnc SERVICES, mac., 130 W. lNTERNATfONAL AIRPORT RD SURE C, ANC~iORAOe, AK 99518 PHONE: X9071245-8951 F/-X: (907)245-88852 E-MAIL : pdsanchorage a(~.memorylog.com WEBSRE : v~ww.memorylog.com ~.. C:1Documents and Settings\Ownec\DesktoplTiansmit BP.dopc STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION RECEII~E, JAN 2 1 2005 REPORT OF SUNDRY WELL OPERATION~~aska n~- R r~~ ~,,.,~ .• 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other ~ ° ~ e Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~~ Exploratory 197-0010 3. Address: P.O. Box 196612 Stratigraphic I~' Service ~~ 6. API Number: Anchorage, AK 99519-6612 50-029-21636-01-00' 7. KB Elevation (ft): 9. Well Name and Number: 64.14 KB PBU G-32A 8. Property Designation: 10. Field/Pool(s): ADLO-028280 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12220 ~ feet Plugs (measured) 11330' 1/18/09 true vertical 9024.69 - feet Junk (measured) 12133 Effective Depth measured 12133 feet true vertical 9026 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 27 - 107 27 - 107 1490 470 Surface 2650 13-3/8" 72# L-80 26 - 2676 26 - 2676 5380 2670 Production 8746 9-5/8" 47# L-80 25 - 8771 25 -8420 6870 4760 Liner 594 7" 26# L-80 8521 - 9115 8188 - 8733 7240 5410 Liner 3815 2-7/8"6.5# L-80 8405 - 12220 25 - 8420 6870 4760 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 20 - 8589 0 0 - Packers and SSSV (type and measured depth) 2-7/8" Top Packer 8405 4-1/2" TIW HBBP-R Packer 8470 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~-,/,( ~ ~ t rPf ~ ~, ~ ~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 708 30364 17 735 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development ~' ' Senrice f Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ ~ Gas ~ WAG ~ GINJ ~ WINJ ~ WDSPL 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 Gary Preble Printed Name Gary Prebl , Title Data Management Engineer Signature Phone 564-4944 Date 1/21/2009 .~ Form 10-404 Revised 04/2006 ~l Submit Original Only G-32A 197-0010 PERF oTTOCHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base G-32A 2120/97 PER 10,740. 10,920. 9,014.09 9,026.55 G-32A 2/20/97 PER 11,010. 11,120. 9,033.48 9,040.3 G-32A 2/20/97 PER 11,600. 11,910. 9,040.2 9,029.69 G-32A 2/20/97 PER 11,960. 12,100. 9,028.99 9,026.45 G-32A 1125/01 BPS 11,350. 11,360. 9,051.34 9,051.25 G-32A 1/26/01 APF 10,380. 10,680. 9,003.55 9,010.25 G-32A 1/26/01 APF 10,740. 10,920. 9,014.09 9,026.55 G-32A 7/12/03 BPP 11,350. 11,360. 9,051.34 9,051.25 G-32A 1/18/09 BPS 11,330. 11,600. 9,051.12 9,040.2 G-32A 1!19/09 APF 10,155. 10,185. 9,017.88 9,015.49 G-32A 1/19/09 APF 10,213. 10,233. 9,013.3 9,012.15 G-32A 1/20/09 APF 10,105. 10,125. 9,016.97 9,018.41 G-32A 1/20/09 APF 10,125. 10,140. 9,018.41 9,018.62 G-32A 1/20/09 APF 10,145. 10,155. 9,018.47 9,017.88 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • G-32A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/18/2009 CTU #9 w/1.75" CT Job Scope: Set CIBP/Add Perf «Interact not publishing» No luck in getting down POOH w/ logging tools. RIH w/ 2.25" Venturi on motor to 11400' with no motor work or tight spots. RIH w/PDS :'memory CCL/GR in carrier & 2.25" JSN make logging pass up for CT flag's 'from 11400'to 10000' OOH w. data recovered indicating a -28.5' correction. 'RIH w/ 2 7/8"CIBP (2.23" OD) Set at 11,330' at mid packer. POOH ,lay 3 Ildown logging tools, MU 20' of Perf guns .... *"'"Job Continued on 01/19/09**"* 1/19/2009 CTU #9 w/1.75" CT Job Scope: Set CIBP/Add Perf «Interact Publishing» MU & RIH w/ 20 ft 2006 PJ, HMX 6spf, 60 deg. phasing Perforate 10213' - ', MU 2nd gun run and perforated 10155'-10185'. POOH and MU GR/CCL and log 10,300' to 10,100'. POOH MU &RIH 3rd gun (35' of shots)... *''*Continued on 01/20/08*"* 1 /20/2009 i CTU #9 w/1.75" CT Job Scope: Set CIBP/Add Perf «Interact Publishing» RIH w/ 30 ft 2006 PJ, HMX 6spf, 60 deg. phasing. Perforate 10125'-10140' (5' blank) 10145'-10155' OOH w. all shots fired. RIH w/20' 2006 PJ, HMX 6spf, 60 deg. phasing. Perforate 10105' - 10125' OOH w. all shots fired. Displace tubing w/ 140 bbls of Diesel. Hand well over to Pad Operator to POP ***Job complete"** FLUIDS PUMPED BBLS 140 diesel 123 2% KCL 165 60/40 METH 691 Total • ~~ --- --,~~ ,~ ProActive Diagnostic Services, Inc. • To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 ~~~ ~ .~~ ~r~ `~~ ~~~ RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245.8952 ~9~-~~ 1) Cail Flag 16-Jan-09 G32A EDE 2j Coil Flag ., 18,Jan-09 G32A EDE L,, . ,. ~, Signed : ~, , ' ,~' Print Name: l~ c/~ /' J "i' =1" 50-029-21636-01 ~50=i~29-~'C3G~1 Date ~ _ ~''~~_ PROACTIVE DIAGNOSTIC SERVICES, MC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 89518 PHONE: (907)245-8961 FAX: (907}245-88952 E-MAIL: tiw~~~~§~~r~~,~°c+_~a~l~*~t~?rl~~,~,~~ WEBSITE:;r~~nnr.~~~1-~r3~~_Y~rs~ i'~ _ C:\Documenis and Settings\0wnerlDesk[op\Transmit BP.docx 04/30/07 Schlumberger NO. 4237 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ICJ?-OOl S'CANNS> MAY 0'7 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WII J b# L D . ti D t BL CI CD . e 0 oa eSCrlp1 on ae o or S-21 11695054 LDL 03/27/07 1 Y-31 11628764 MEM GLS 04/03/07 1 14-04 11660530 MEM PROD PROFILE 04/06/07 1 14-10 11626084 LDL 04/02/07 1 F-17A 11626083 LDL 03/31/07 1 F-30 11626078 LDL 03/26/07 1 X-21A 11660531 MEM PROD PROFILE 04/07/07 1 G-32A 11661134 MEM PROD PROFILE 03/30/07 1 X-36 11649959 MEM INJECTION PROFILE 04/12/07 1 06-24A 11637328 PRODUCTION PROFILE 04/16/07 1 X-36 11649959 MEM INJECTION PROFILE 04/12/07 1 12-02 NIA MEM INJECTION PROFILE 04/14/07 1 J-12 11686735 PROD PROFILE 04/13/07 1 B-26B 11628767 MEM PROD PROFILE 04/11/07 1 11-36 11626477 PROD PROFILE 04/17/07 1 03-18A 11626081 LDL 03/30/07 1 P2-59A 11630470 US IT 04/02/07 1 11-37 11626086 PRODUCTION PROFILE 04/22/07 1 X-10 11686739 LDL 04/23/07 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: ~1AY 0 4 Z007 Received by: r)!~t~ (Jil & G~ COilS. C;Qffimissioo AOO1ri~ (l. RECEIVED Scblulllberger dUN 1 4 2006 o( C)l{/D I", r 1- -# 1 <311 ':) ª(;¡\~NE~<¿ 2 :~) 2DÜYj Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 NO. 3843 Alaska Data & Consulting SeMJRka Oil & (~as (;<)(\$. commission 2525 Gambel/ Street, Suite 400 An(;~ Anchorage, AK 99503-2838 A TTN: Beth Field: Prudhoe Bay WIi C e Job# Log Description Date BL Color D 15-20B 10669980 MCNL 10112103 1 1 G-32A 10942216 MCNL 05131105 1 1 NK-65A 11221860 RST 02123106 1 1 L2-28 NIA RST 11104105 1 1 L2 -28 . 11226951 RST 04107106 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Sune 400 Anchorage, AK 99503-2838 A TIN: Beth (\\ ", ~!'1, ¡ i k)" //\",,~.~., ,/ ",,,.,1 ".... ....' c'¡ I'j I ti:, 06/09/06 e e 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D ) STATE OF ALASKA ) RECEIV¡ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUL 1 3 20( Aroska Oil & Gas Cons. (; OtheAiiahorage Time ExtensionD Re-enter Suspended WellD Repair WellO Pull TubingD Operation Shutdown 0 Pluç¡ Perforations 0 Perforate New Pool D Perforate D Stimulate 00 WaiverD 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development [!] ExploratoryD 5. Permit to Drill Number: 197-0010 6. API Number 50-029-21636-01-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.14 8. Property Designation: ADL-028280 11. Present Well Condition Summary: StratigraphicD ServiceD 9. Well Name and Number: G-32A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 12220 feet true vertical 9024.7 feet Effective Depth measured 12133 feet true vertical 9026.0 feet Plugs (measured) None Junk (measured) CIBP Milled & Pushed to 12133 (07/12/2003) Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 27 107 27.0 107.0 1490 470 LINER 594 7" 26# L-80 8521 - 9115 8188.0 - 8732.9 7240 5410 LINER 3815 2-7/8" 6.5# L-80 8405 - 12220 8080.1 - 9024.7 10570 11160 PRODUCTION 8746 9-5/8" 47# L-80 25 - 8771 25.0 - 8419.6 6870 4760 SURFACE 2650 13-3/8" 72# L-80 26 - 2676 26.0 - 2675.7 5380 2670 Perforation depth: Measured depth: 10380 -10680,10740 -10920,11010 -11120,11600 -11910,11960 -12100 True vertical depth: 9003.55 - 9010.25, 9014.09 - 9026.55, 9033.48 - 9040.3, 9040.2 - 9029.69, 9028.99 - 9026.45 Tubinç¡ ( size, ç¡rade, and measured depth): 4-1/2" 12.6# L-80 @ 20 8581 ,SCl:\NNEO JUl 1 4 2005 Packers & SSSV (type & measured depth): 2-7/8" Top Packer 4-1/2" TIW HBBP-R Packer 4-1/2" Otis Landing Nipple @ 8405 @ 8462 @ 2089 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Oil-Bbl Representative Dailv Averaqe Production or Injection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure 13 Prior to well operation: Subsequent to operation: ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ) Service 0 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr Signature ~.J."1r.' ~J ~ Title Petroleum Engineer RBJJJ1~gUl :~:'52:: Date 7/13/05 Form 10-404 Revised 4/2004 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/30/05 CTU #4 MCNUACID WASH ***WELL SHUT IN UPON ARRIVAL*** RIH W/ SLB MCNL. LOG FROM 121001 TO 9000' CTMD. 05/31/05 CTU#4: MCNUACID/N2 FLOWBACK. CONTINUE LOGGING 2ND MCNL PASS. POOH. RIH W/ 2" JSN. PERFORM INJECTIVITY TEST - (WHP - 1585 PSI & CTP 3867 PSI) @ 1.7 BPM. SPOT 20 BBLS OF 7.5% HCL ACID ACROSS PERFS (10380· - 11120') & LET SOAK 30 MINUTES. FINAL INJECTION RATE = WHP - 302 PSI / CTP - 2525 PSI @ 1.7 BPM. PUH & OPEN WELL THRU TEST SEP. FOR RETURNS. CT @ 2000' & PUMP N2 @ 500 SCFM TO LIFT IN WELL. RIH TO LIFT IN WELL. CT @ 65001 & LIFT WELL IN FROM THIS POINT. SHUT DOWN N2 & OBSERVE WELL TO SEE IF IT WILL FLOW ON ITS OWN. FLUID RETURN RATE @ 1900 BPD. 314 BBLS RETURNED. PH-4. 4 MMCFD GAS 500/0 WATER CUT. CT ON SURFACE & OBSERVE WELL. LEFT WELL FLOWING THRU ASRC @ 5 MMSCFPD GAS, 1800 BFPD, 180/0 WC, PH=5, WHP = 1000 PSI, WHT = 58 DEG F. RDMO. ***JOB COMPLETE*** 06/03/05 ASRC POST ACID STIM WELL TEST:. . 1880 BFPD. 1826 BOPD. 3% W/C. 8.3 MMSCF/D. 0.0 MM G/L. 176 BEANS FLUIDS PUMPED BBLS 88 50/50 METHANOL WATER 191 DIESEL 170 FILTERED 1 % KCL 70 7.5% HCL 2210 GALLONS N2 519 TOTAL Page 1 ') TREE = 4" CIW W8..LHEAD = I\,tEVOY A'crÐÃ'TÕFr;'''A'XËLSÕ'N' KB. ELEV = "i:j¿r1' 'Bf't[êl·':;""''''''''''''''''''''''''35~'92ì "'",..',"'~' ..... ....,·~,"..,·,,',.w" ,.,n . ..' ......,. .," ""."."w KOP = 4192' ..".......,"....,.......~"',,''''................,.,''..'.............''n'........,''...................... Max Angle = 95 @ 10184' Datum MD = 9269' ÖäiUmNö;m, , "8Sö'ÒïSS 13-3/8"CSG, 72#, L-80, D = 12.347" '<b,?,/. ~ 1--1 &G&1' r-- 9-5/8" CSG, 47#, L-80, ID = 8.681" 1--1 1 TOP OF 9-518" CSG 1-1 4268' 4268' 1 TOP OF 2-7/8" LNR l-i 8405' Minumum ID = 2.37" @ 8405' 2-7/8" LINER TOP, PIN ID 1 TOP OF 7" LNR H 8529' 4-1/2" T8G, 12.6#, L-80, .0152 bpf, ID= 3.958" l-t 85 'all ~I I S 7'71 ~ ----A 9-5/8" CSG, 47#, L-80, ID = 8.681" l-t PERF ORA 1l0N SUMtvlA.RY REF LOG: SPERRY SUN MWD/GR ON 01/25/97 ANGLEATTOPPERF:86@ 10740' Note: Refer to Production œ for historical perf data SIZE SPF INTER\! AL OPNlSOZ DA TE 1-11/16" 4 10740-10920 0 02120/97 1-11/16" 4 11010-11120 0 02120/97 1-11/16" 4 11600-11910 0 02120/97 1-11/16" 4 11960-12100 0 02120/97 2" 6 10380 - 10680 0 01/26/01 2" 6 10740 - 10920 0 01/26/01 1 TOP OF WHIPSTOCK H 9120' T' LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 9115' G-32A - , I I ~ ~ ') SAFETY NOTE: TTRD SIDETRACK COMPLETlON. HORIZONTAL WELL - 70° @ 9459' AND 90° @ 9646' 2089' H 4-1/2" SSSV 011S LNDNG NIP, ID = 3.813" ~ I 8396' 11 4-1/2" OTIS XA SLIDING SL V, ID = 3.813" 1 1 8405' 1-14-1/2" X 2-7/8' PKRlI-GRWrnEBAO<, D =2.370" 1 8426' 1-1 TOC IN 4-1/2" X 2-7/8" A NNlJ...US 1 1 8455' 1-1 llW SBR TBG SEAL ASSY I 8470' 1-1 9-518" X 4-1/2" TIW HBBP PKR, ID = 4.750" 8518' 1-1 4-1/2" OTIS X NIP, ID =3.813" I 8555' l-i 4-1/2" MILLEDOT6 XN NIP, ID=3.8" 8589' 1-1 4-1/2" 1BG TAIL 1-1 8..MD TT NOT LOGGS) SIDElRAO< WINDOW 9115' - 9122' aBP- MILLS) & PUSHEDTOTD (07//:<'/03) tl FBTD H 12125' 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID = 2.441" H 12220' OA.TE 08/22/86 02f20/97 02/15/01 03/05/01 02/0 1 /02 07/12/03 OOM\t1S\JTS DA TE REV BY COMrvENTS ORGINAL COI'vPLETION 07/14/03 CMOffLP KB ELEV A TION OORRECTION TTRD SIDErRACK COMR..ETION CONV ERTs) TO CA. NV AS FINAL CORRECTONS MILL/PUSH CIBP TO 1D PRLOI-DE BA Y U\JrT WELL: G-32A PERMrr No: 1970010 AR No: 50-029-21636-01 SEC 12, T11N, R13E, 1922' St\L & 4312' W8.. RBI BY 56-lsl S 1& fvÐ RNITP TMN/KK BP Exploration (Alaska) ( STATE OF ALASKA ( ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator SuspendD Repair Well 0 Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate D VarianceD Annular DisposalD Stimulate 0 Time Extension 0 Other I]] Re-enter Suspended Well 0 Mill CIBP 5. Permit to Drill Number: 197-001 0 Name: BP Exploration (Alaska), Inc. Development ŒJ Stratigraphic D 9. Well Name and Number: G-32A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Exploratory 0 Service 0 6. API Number 50-029-21636-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.14 8. Property Designation: ADL-0028280 11. Present Well Condition Summary: Total Depth measured 12220 feet true vertical 12133 feet 9026.0 feet Plugs (measured) Junk (measured) 12133 true vertical 9024.7 feet Effective Depth measured None Casing Length Size MD TVD Burst Collapse Conductor 110 20" 91.5# H-40 35 145 35.0 - 145.0 1490 470 Liner 3815 2-7/8" 6.5# L-80 8405 - 12220 8080.1 - 9024.7 10570 11160 Liner 586 7" 26# L-80 8529 - 9115 8195.5 - 8732.9 7240 5410 Production 8746 9-5/8" 47# L-80 33 - 8779 33.0 - 8427.0 6870 4760 Surface 2650 13-3/8" 72# L-80 34 - 2684 34.0 - 2683.7 4930 2670 Perforation depth: Measured depth: 10380 -10680,10740 -10920,11010 -11120,11600 -11910,11960 -12100 True vertical depth: 9003.55 - 9010.25, 9014.09 - 9026.55, 9033.48 - 9040.3, 9040.2 - 9029.69, 9028.99 - 9026.~ E eEl VE D Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 28 - 8589 DEC 172003 Alaska Oil & Gas Cons. Commission Anchora e Packers & SSSV (type & measured depth): 2-7/8" Liner Top Packer 4-1/2" TIW HBBP-R Packer @ @ 8405 8470 12. Stimulation or cement squeezesummary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Prior to well operation: Subsequent to operation: Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure 362 10.98 7 612 429 13.2 9 102 14. Attachments: 15. Well Class after proposed work: Exploratory 0 Development ŒJ Service D Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Title Production Technical Assistant Signature Form 10-404 Revised 4/2003 s,CA~~E1D, DEC 2 12003 ~ btL Phone 564-4657 Date 12/17/03 f")lr"',~ ! i ,r ( ( G-32A DESCRI PTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/02/03 DRIFT W/2.25in CENT SAMPLE BAILER TO 93921 SLM STOPPED DUE TO DEVIATION NO SAMPLE 07/11/03 MIRU CTU #5. MU/RIH W/ WEATHERFORD 2 1/81111 MOTOR/ 2.2921111 4-BLADE JUNK MILL. TAG CIBP @ 113531. ATTEMPT TO MILL. LOAD BACKSIDE W/ CRUDE. RETAG PLUG @ 113801. ATTEMPT TO MILL. POOH TO CK BHA. MU NEW MOTOR AND CHECK MHA FOR OBSTRUCTIONS. RIH WI MOTOR #2 NEW 5 BLADE JUNK MILL (2.291111.) TAG PLUG @ 113901, PUSH/MILL TO 113961. JOB IN PROGRESS.II 07/12/03 MILLING CIBP IN PROGRESS .... PUSH/MILL PLUG FROM 11380' TO 12133' CTM. ALL PERFS CLEAR - 331 RA THOLE. DISPLACE WELL OVER TO CRUDE WHILE POOH. NOTIFY PAD OPER TO POP & TEST. FLUIDS PUMPED BBLS 481 2% XS KCL 26 Flo-Pro 233 Crude 68 50/50 Methanal/H2O 808 TOTAL Page 1 J .. .., " TREE = 4"CrN ( W 8.. LI-EA D = rvtEVOY A crUA TOR = AXELSON KB. ELEV = 64.1' BF. ELEV = 35.92' KOP= 4192' Max Angle = 95 @ 10184' DatumMD= 9269' DatumTVD = 8800' SS 13-318" CSG, 72#, L-80, D = 12.347' 2684' 9-5/8" CSG, 47#, L-80, ID = 8.681" I TOP OF 9-518" CSG H 4268' 4268' TOP OF 2-7/8" LNR 8405' Minumum ID = 2.37" @ 8405' 2-718" UN ER TOP, PIN ID TOP OF 7' LNR 8529' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 8589' 9-518" CSG, 47#, L-80, ID = 8.681" I 8779' PERFORA TlON SUMrv\A.RY REF LOG: SPERRY SUN MWD/GR ON 01/25/97 ANGLEATTOPPERF:86@ 10740' Note: Refer to Production œ for historieal perf data SIZE SPF INTER\! AL OPN'Sæ Dð.TE 1-11/16" 4 10740 - 10920 0 02120/97 1-11/16" 4 11010 -11120 0 02120/97 1-11/16" 4 11600-11910 C 02120/97 1-11/16" 4 11960 -12100 C 02120/97 2" 6 10380 - 10680 0 01/26/01 2" 6 10740 - 10920 0 01/26/01 I TOP OF WHIFSTOCK I 7' LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 9120' 9115' ( G-32A SAÆTY NOTE: TTRD SIDETRACK COMPLE110N. HORIZONTAL WELL - 70° @ 9459' AND 90° @ 9646' I) 2089' 4-1/2' SSSV OTIS LNDNG NIP, ID = 3.813" 8396' 4-1/2" OTISXA SLIDING SLV, ID= 3.813" I I 8405' 8426' 8455' 4-1/2" X 2-7/8' PKRlI-K3R W/TIEBAO<, D = 2.370" TlW SBR TBG SEAL ASSY -I 9-518" X 4-1/2" TIW HBBP PKR, ID = 4.750" I 4-1 f2" OTIS X NIP, ID = 3.813" 8470' 8518' 4-1/2" MLLEDOT6 XN NIP, ID=3.8" 8555' 8589' -I 4-1/2"TBGTAIL 1-1 El.rvD TT NOT LOGGED I I SIŒTRA 0< IMi'ÐQW 9115' - 9122' asp - MLLED & PUS !-ED TO TD 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID = 2.441" I 12220' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/22/86 ORGINAL COrvPLETION 07/14/03 CrvIOffLP KB ELEV A TION CORRECTION 02/20/97 TTRD SIDEfRACK COMR..ETlON 02/15/01 SIS-isl CON\! ERTED TO CA N\! AS 03/05/01 S IS- MD FINAL 02/01/02 RN/TP CORRECTONS 07/12/03 TMN/KK MILL/PUSH CIBP TO TO PRUDHOEBA Y U\JIT WELL: G-32A PERMIT No: 1970010 AA No: 50-029-21636-01 SEC12, T11N, R13E, 1922' Sf\L &4312'WEl. BP Exploration (Alas ka) MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, DATE' March 26, 2001 Commissioner Tom Maunder, P. I. Supervisor FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit BPX/G Pad March 26, 2001: I traveled to BPX's Prudhoe Bay Field, G Pad, to witness Surface Safety Valve System tests and perform well house inspections.' Merv Liddelow was the BPX representative in charge of testing and he performed the tests in a safe and proficient manner. Fifteen wells were tested with nine failures witnessed. The pilots on wells G-02A, G-1 lA, G-14A and G- 21A failed to operate properly. The $$V's on wells G-01A, G-02A, G-03A, G-09 and G-13 failed to close or failed to hold D/P. Wells G-03 and G-09 were shut in pending repairs. Mr. Liddelow indicated to me that all other failures had been repaired and passed a retest within 24 hours. Fifteen well houses were inspected and slight crude oil leaks were noted on wells G-14 and G-16. Mr. Liddelow and his crew repaired these leaks immediately. The AOGCC test reports are attached for reference. SUMMARY: I witnessed SVS tests on 15 oil producing wells on BPX's G Pad in the Prudhoe Bay Field. 15 wells, 30 components tested. 9 failures: 30% failure rate. 15 well house inspections A.tt.achm.ents: SVS PBU G Pad 3-26-01 JJ CC;: NON;,C, O. NFIOENTIA. L SVS PBU G Pad 3-26-01 JJ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOCJCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit/Pad: PBF/PBU/G-Pad , Separator psi: LPS 152 Date: 3/26/01 HPS 649 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code , ,~0de, P~ssed GAS or CYCLE G-01A 1931710 649 550 565 P 5 OIL G-02A '1950230 152 1'25 145 1" 5 .... 0iL G-03A 1970700 152 '125 '115. e 5 ' OIL ~-04A 1951630 ........ G-05 1780970 649 550 555 P P ' OIL (}-06 1790'i20 .... G-07 1790180 152 '125' '115 P " P "' OIL .... ,, , , , , G-08 1810480 ~-09A'' j 1982~30 64~ 550 560 e '4 .... OIL G-10A 1950390 G-11A' 1931'600 ' 649 550 180 3 e oIL G-12A 1961050 ,, , , ,, G-13 1810720' 152 125 120 P 4 OIL G-14A 1980530 649 550 0 2 P OIL G-15A 1981340 64~ 55'0 5~0 P P ' OIL ~-16'" 1811220' 649 550 ' 540 P P ~ " 'G-17 1810940 :G-18A 1990320 649 ' ~50 '5551 P P ' OIL . , G-19A 1991030 G-21 1951540 649 550 0 2 P OIL iG-23A 1960200 , , G-24 1861830 G-25 1861620 G-26A 1981510 G_2~' 18'61560 '" G-29 1861600 ..... G-30/~ 1950760 ' G-31A _~.1980540 '649 550 560 " P P '' OIL 'G-32A 1970010 152 125 140 P P OIL Wells: 15 Components: 30 Failures: 9 Failure Rate: 30.00o/t~] 90 I)a¥ Remarks: G-3, G-9 are shut in for repair. Operator reports all other failures repaired & pas...sed r~ RJF 1/16/01 Page 1 of 2 SVS PBU G Pad 3-26-01 JJ1 - [ Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number ,, PSI PS!, ,Tr!p Code Code Code Passed GAS orCYCLE, RJF 1/16/01 Page 2 of 2 SVS PBU G Pad 3-26-01 JJ1 PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 01/21/99 RUN RECVD 97-001 NGP-MD 97-001 NGP-TVD 97-001 8001 97-001 MWD SRVY ~.~9129-12221 G~/8744-9024 GR/ROP FINAL 05/21/97 FINAL 05/21/97 06/20/97 06/03/97 lO-~O7 ,~o~TzO~ DAT~ 2./~/q? Are dry ditch samples required? yes ~,~d received? Was the well cored? yes ~-Analysis & description received? Are well tests required? yes n~ Received? y~ Well is in compliance Initial COMMENTS sper, r, -sun I-I 11:::! I I__ I__ I fl] I~ S I::::: !::! ~J I r- I::::: S WELL LOG TRANSNHTTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~'~1 MWD Formation Evaluation Logs - G-32A, AK-MW-70018 June 25,1997 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' J~m Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-21636-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ~ . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COIV~MlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil [] Gas [] Suspended E~] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-01 3. Address i'~,,,A~~ 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21636-01 4. Location of well at surface ~r '":;':i;'i?:'i-i':_:;i:i":';t ~,,....,~"""~ 9. Unit or Lease Name 2299' SNL, 2369' WEL, SEC. 12, T11 N, R13E, UPU! _ /;:.,/;..:~ ~ l_.~~ Prudhoe Bay Unit At top of productive interval ! -~'- '---'~- -~-_~_? ~ 10. Well Number - ~;'~-;';i!:'~;!5 ¢' G-32A 342' NSL, 3381' WEL, SEC. 1, T11N, R13E, UPU ;/%¢"'~ - At total depth 11. Field and Pool 542' NSL, 4847' WEL, SEC. 1, T11N, R13E, UPU ....... '~ ...... ~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 64.14'I ADL 028280 12. Date Spudded1/25/97 113' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' water depth' if Offsh°re I 16' N°' °f C°mpletiOns2/16/97 2/20/97 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12220 9024 FTI 12125 9025 FTI [~Yes []No1 (Nipple) MDI 1900' (Approx.) 22. Type Electric or Other Logs Run 0RI¢.! NAL MWD, GR, RES, LWD (D,R/DD) 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE S~ZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" Insulated Conductor Surface 110' 9 cu yds concrete 13-3/8" 72# L-80 Surface 2682' 17-1/2" 2358 cuff PF 'E', 465 cu ft PF 9-5/8" 47# L-80 NSCC Surface 4269' 12-1/4" 9-5/8" 47# L-80 Butt 4269' 8779' 12-1/4" 575 cu ft Class 'G' 7" 26# IJ4S 8529' 9115' 8-1/2" 413 cu ft Class 'G' · 2-7/8" 6.4# L-80 8415' 12220' 3-3/4" 200 cu ft Class 'G ........ ._. 24. Perforations open to Production (MD+TVD of Top and 25. TUBING R"E~'~'~ Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 1-11/16" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 8589' 8470' MD TVD MD TVD 10740' - 10920' 9013' - 9026' 11010' - 11120' 9033' - 9040' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11600' - 11910' 9039' - 9029' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11960' - 12100' 9028' - 9026' Freeze Protect with 35 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 14, 1997 F owing Date of Test Hours Tested PRODUCTION FOR O~L-BBL GAS-MCF WATER-DEL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 128. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Zone 2C 9106' 8724' Zone 2B 9156' 8768' Zone 2A 9319' 8902' Zone 1B 9455' 8973' 13P 10737' 9013' 11 N 11116' 9039' 31. List of Attachments Summary of Daily Drilling Reports, Surveys Dan Stoltz ,~/~//~/"',~ ./---/~Z¥.,'~/.,,//' Title Senior Drilling Engineer Date '---'~ G-32A - (-297-01 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility PB G Pad Progress Report Well G-32A Rig Doyon 16 Page Date 1 22 May 97 Date/Time 21 Jan 97 22 Jan 97 23 Jan 97 24 Jan 97 25 Jan 97 10:00-17:30 17:30-23:30 23:30-03:00 03:00-06:00 06:00-06:30 06:30-12:30 12:30-13:30 13:30-14:30 14:30-17:00 17:00-18:00 18:00-18:30 18:30-20:00 20:00-21:30 21:30-00:30 00:30-02:00 02:00-05:00 05:00-06:00 06:00-06:30 06:30-11:00 11:00-11:15 11:15-15:30 15:30-16:00 16:00-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-00:30 00:30-00:45 00:45-01:00 01:00-01:30 01:30-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-08:30 08:30-08:45 08:45-15:30 15:30-18:00 18:00-18:30 18:30-19:00 19:00-19:15 19:15-00:30 00:30-01:00 01:00-02:00 02:00-06:00 06:00-06:30 06:30-07:00 07:00-12:00 12:00-12:15 12:15-15:30 15:30-16:30 16:30-18:00 18:00-18:30 18:30-19:00 Duration 7-1/2 hr 6 hr 3-1/2 hr 3 hr 1/2 hr 6hr lhr lhr 2-1/2 hr lhr 1/2 hr 1-1/2 hr 1-1/2 hr 3 hr 1-1/2 hr 3 hr 1 hr 1/2 hr 4-1/2 hr 1/4 hr 4-1/4 hr 1/2 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 6 hr 1/4 hr 1/4 hr 1/2 hr 4-1/2 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 1/4 hr 6-3/4 hr 2-1/2 hr 1/2 hr 1/2 hr 1/4 hr 5-1/4 hr 1/2 hr 1 hr 4hr 1/2 hr 1/2 hr 5 hr 1/4 hr 3-1/4 hr 1 hr 1-1/2 hr 1/2 hr 1/2 hr Activity Rig moved 95.00 % Rigged down BOP stack Rig moved 100.00 % Removed Xmas tree Held safety meeting Rigged up BOP stack Rigged up Kelly Tested BOP stack Rigged down Lubricator Rigged up BOP stack Held safety meeting Tested BOP stack Rigged up Lubricator Made up BHA no. 1 Rigged up Drillstring handling equipment Singled in drill pipe to 1450.00 ft Rigged up Kelly Held safety meeting Singled in drill pipe to 3870.00 ft Held drill (Kick while tripping) Singled in drill pipe to 8535.00 ft Milled Landing collar at 8535.00 ft Singled in drill pipe to 9115.00 ft ~ Milled Casing at 9115.00 ft Held drill (Spill) Held safety meeting ~"~Milled Casing at 9122.00 ft Held drill (Fire) Held drill (H2S) Circulated at 9122.00 ft Pulled out of hole to 3000.00 ft Held safety meeting Pulled out of hole to 0.00 ft Pulled BHA Made up BHA no. 2 Held drill (Fire) R.I.H. to 9115.00 ft Milled Casing at 9118.00 ft Held safety meeting Milled Mud motor at 9120.00 ft Held drill (Kick while drilling) Pulled out of hole to 0.00 ft Pulled BHA Made up BHA no. 3 R.I.H. to 7000.00 ft Held safety meeting R.I.H. to 9122.00 ft Drilled to 9128.00 ft Flow check Pulled out of hole to 0.00 ft Pulled BHA Made up BHA no. 4 Held safety meeting Made up BHA no. 4 Facility Date/Time 26 Jan 97 27 Jan 97 28 Jan 97 29 Jan 97 PB G Pad Progress Report Well G-32A Rig Doyon 16 Page Date Duration Activity 19:00-23:30 23:30-00:30 00:30-02:00 02:00-02:30 02:30-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-09:15 09:15-09:30 09:30-12:30 12:30-13:30 13:30-15:30 15:30-18:00 18:00-18:30 18:30-20:30 20:30-22:00 22:00-22:15 22:15-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-10:30 10:30-11:00 11:00-11:30 11:30-11:45 11:45-18:00 18:00-18:30 18:30-22:00 22:00-22:15 22:15-22:45 22:45-23:45 23:45-00:00 00:00-04:30 04:30-05:45 05:45-06:00 06:00-06:30 06:30-10:00 10:00-12:00 12:00-13:00 13:00-13:15 13:15-13:30 13:30-16:30 16:30-18:00 18:00-18:30 18:30-21:00 21:00-21:15 21:15-22:30 22:30-06:00 06:00-06:30 06:30-09:30 09:30-09:45 09:45-18:00 4-1/2 hr 1 hr 1-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr 1 hr 1/4 hr 1/4 hr 3 hr 1 hr 2 hr 2-1/2 hr 1/2 hr 2 hr 1-1/2 hr 1/4 hr 4-3/4 hr 2 hr 1 hr 1/2 hr lhr 3 hr 1/2 hr 1/2 hr 1/4 hr 6-1/4 hr 1/2 hr 3-1/2 hr 1/4 hr 1/2 hr 1 hr 1/4 hr 4-1/2 hr 1-1/4 hr 1/4 hr 1/2 hr 3-1/2 hr 2 hr 1 hr 1/4 hr 1/4 hr 3hr 1-1/2 hr 1/2 hr 2-1/2 hr 1/4 hr 1-1/4 hr 7-1/2 hr 1/2 hr 3 hr 1/4 hr 8-1/4 hr R.I.H. to 9097.00 ft Washed to 9128.00 ft Drilled to 9155.00 ft Circulated at 9155.00 ft Drilled to 9218.00 ft Held safety meeting Drilled to 9265.00 ft Circulated at 9265.00 ft Flow check Held drill (Fire) Pulled out of hole to 0.00 ft Pulled BHA Made up BHA no. 5 R.I.H. to 6000.00 ft Held safety meeting R.I.H. to 9265.00 ft Drilled to 9268.00 ft Flow check Pulled out of hole to 0.00 ft Downloaded MWD tool R.I.H. to 1500.00 ft Held safety meeting Serviced Block line R.I.H. to 9017.00 ft Set tool face R.I.H. to 9268.00 ft Held drill (H2S) Drilled to 9403.00 ft Held safety meeting Drilled to 9484.00 ft Flow check Pulled out of hole to 9120.00 ft Circulated at 9484.00 ft Flow check Pulled out of hole to 0.00 ft Pulled BHA Held drill (Fire) Held safety meeting R.I.H. to 9414.00 ft Washed to 9420.00 ft Circulated at 9420.00 ft Flow check Held drill (Kick while drilling) Pulled out of hole to 0.00 ft Pulled BHA Held safety meeting R.I.H. to 5755.00 ft Held drill (Kick while tripping) R.I.H. to 9420.00 ft Drilled to 9520.00 ft Held safety meeting Drilled to 9540.00 ft Held drill (Spill) Drilled to 9640.00 ft 2 22 May 97 Facility Date/Time 30 Jan 97 31 Jan 97 01 Feb 97 02 Feb 97 Progress Report PB G Pad Well G-32A Page 3 Rig Doyonl6 Date 22May97 18:00-18:30 18:30-22:00 22:00-23:00 23:00-23:15 23:15-23:30 23:30-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-08:30 08:30-09:00 09:00-12:00 12:00-13:00 13:00-13:15 13:15-14:00 14:00-14:30 14:30-18:00 18:00-18:30 18:30-23:00 23:00-23:15 23:15-06:00 06:00-06:30 06:30-07:30 07:30-08:15 08:15-08:30 08:30-11:30 11:30-12:00 12:00-12:30 12:30-12:45 12:45-16:30 16:30-18:00 18:00-18:30 18:30-22:30 22:30-23:00 23:00-23:15 23:15-23:30 23:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-09:30 09:30-10:30 10:30-12:00 12:00-12:30 12:30-16:00 16:00-16:15 16:15-16:30 16:30-18:00 18:00-18:30 18:30-20:00 20:00-21:30 21:30-22:00 22:00-02:00 02:00-03:00 Duration 1/2 hr 3-1/2 hr 1 hr 1/4 hr 1/4 hr 5-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2 hr 1/2 hr 3hr 1 hr 1/4 hr 3/4 hr 1/2 hr 3-1/2 hr 1/2 hr 4-1/2 hr 1/4 hr 6-3/4 hr 1/2 hr 1 hr 3/4 hr 1/4 hr 3 hr 1/2 hr 1/2 hr 1/4 hr 3-3/4 hr 1-1/2 hr 1/2 hr 4 hr 1/2 hr 1/4 hr 1/4 hr 5 hr 1 hr 1/2 hr 1/2 hr 3 hr 1 hr 1-1/2 hr 1/2 hr 3-1/2 hr 1/4 hr 1/4 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 4 hr 1 hr Activity Held safety meeting Drilled to 9723.00 ft Circulated at 9723.00 ft Held drill (Fire) Flow check Pulled out of hole to 0.00 ft Pulled BHA Tested BOP stack Held safety meeting Tested BOP stack Made up BHA no. 8 R.I.H. to 9028.00 ft Serviced Block line Held drill (Kick while tripping) R.I.H. to 9723.00 ft Logged hole with LWD: DIR/DD from 9689.00 ft to 9723.00 ft Drilled to 9754.00 ft Held safety meeting Drilled to 9827.00 ft Held drill (H2S) Drilled to 9930.00 ft Held safety meeting Drilled to 9930.00 ft Circulated at 9930.00 ft Flow check Pulled out of hole to 0.00 ft Pulled BHA Made up BHA no. 9 Held drill (Spill) R.I.H. to 9930.00 ft Drilled to 9942.00 ft Held safety meeting Drilled to 9956.00 ft Circulated at 9956.00 ft Flow check Held drill (Kick while tripping) Pulled out of hole to 0.00 ft Pulled BHA Made up BHA no. 10 Held safety meeting R.I.H. to 9120.00 ft Serviced Block line Washed to 9276.00 ft R.I.H. to 9956.00 ft Drilled to 9985.00 ft Held drill (H2S) Flow check Pulled out of hole to 4000.00 ft Held safety meeting Pulled out of hole to 0.00 ft Pulled BHA Made up BHA no. 11 R.I.H. to 9120.00 ft Washed to 9184.00 ft Facility Date/Time 03 Feb 97 04 Feb 97 05 Feb 97 06 Feb 97 PB G Pad 03:00-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-10:30 10:30-11:30 11:30-11:45 11:45-15:00 15:00-16:30 16:30-16:45 16:45-18:00 18:00-18:30 18:30-21:30 21:30-22:30 22:30-00:00 00:00-04:00 04:00-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-08:00 08:00-08:15 08:15-18:00 18:00-18:30 18:30-23:00 23:00-00:30 00:30-00:45 00:45-05:00 05:00-05:15 05:15-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-08:30 08:30-08:45 08:45-09:30 09:30-10:30 10:30-11:00 11:00-14:00 14:00-15:00 15:00-18:00 18:00-18:30 18:30-19:00 19:00-23:00 23:00-04:00 04:00-06:00 06:00-06:30 06:30-09:00 09:00-09:15 09:15-18:00 18:00-18:30 18:30-01:30 01:30-01:45 01:45-06:00 Duration 1/2 hr 1/2 hr 2 hr 1/2 hr 4 hr 1 hr 1/4hr 3-1/4 hr 1-1/2 hr 1/4hr 1-1/4 hr 1/2 hr 3hr 1 hr 1-1/2 hr 4 hr lhr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/4 hr 9-3/4 hr 1/2 hr 4-1/2 hr 1-1/2 hr 1/4 hr 4-1/4 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/4 hr 3/4 hr 1 hr 1/2 hr 3 hr 1 hr 3 hr 1/2 hr 1/2 hr 4 hr 5 hr 2hr 1/2 hr 2-1/2 hr 1/4 hr 8-3/4 hr 1/2 hr 7 hr 1/4 hr 4-1/4 hr Progress Report Well G-32A Rig Doyon 16 Page Date Activity R.I.H. to 9972.00 ft Fished at 9972.00 ft Pulled out of hole to 8000.00 ft Held safety meeting Pulled out of hole to 0.00 ft Pulled BHA Held drill (Fire) R.I.H. to 9973.00 ft Fished at 9973.00 ft Flow check Pulled out of hole to 8500.00 ft Held safety meeting Pulled out of hole to 0.00 ft Laid down fish Made up BHA no. 13 R.I.H. to 9388.00 ft Washed to 9508.00 ft R.I.H. to 9956.00 ft Circulated at 9985.00 ft Held safety meeting Drilled to 9999.00 ft Held drill (Kick while drilling) Drilled to 10074.00 ft Held safety meeting Drilled to 10110.00 ft Circulated at 10110.00 ft Flow check Pulled out of hole to 0.00 ft Held drill (Spill) Pulled BHA Made up BHA no. 14 Held safety meeting Functioned downhole tools at 143.00 ft R.I.H. to 3000.00 ft Held drill (Fire) R.I.H. to 9050.00 ft Serviced Block line R.I.H. to 10110.00 ft Drilled to 10187.00 ft Circulated at 10187.00 ft Pulled out of hole to 0.00 ft Held safety meeting Pulled BHA Made up BHA no. 15 R.I.H. to 10187.00 ft Drilled to 10219.00 ft Held safety meeting Drilled to 10251.00 ft Held drill (Spill) Drilled to 10441.00 ft Held safety meeting Drilled to 10501.00 ft Held drill (Kick while drilling) Drilled to 10596.00 ft 4 22 May 97 Facility PB G Pad Progress Report Well G-32A Rig Doyon 16 Page Date 5 22 May 97 Date/Time 07 Feb 97 08 Feb 97 09 Feb 97 06:00-06:30 06:30-07:30 07:30-07:45 07:45-11:00 11:00-12:00 12:00-14:30 14:30-15:30 15:30-17:00 17:00-17:15 17:15-18:00 18:00-18:30 18:30-20:00 20:00-23:30 23:30-00:30 00:30-00:45 00:45-01:00 01:00-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-11:00 11:00-11:15 11:15-12:30 12:30-13:30 13:30-14:30 14:30-18:00 18:00-18:30 18:30-21:00 21:00-21:15 21:15-21:30 21:30-03:00 03:00-04:00 04:00-04:15 04:15-06:00 06:00-06:30 06:30-09:30 09:30-10:30 10:30-12:00 12:00-15:00 15:00-16:00 16:00-16:15 16:15-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-06:00 06:00-06:30 06:30-14:00 14:00-14:15 14:15-15:30 15:30-16:30 16:30-16:45 16:45-17:45 17:45-18:00 Duration 1/2 hr 1 hr 1/4 hr 3-1/4 hr 1 hr 2-1/2 hr lhr 1-1/2 hr 1/4 hr 3/4 hr 1/2 hr 1-1/2 hr 3-1/2 hr lhr 1/4 hr 1/4 hr 4hr 1 hr 1/2 hr 1-1/2 hr 3 hr 1/4 hr 1-1/4 hr lhr 1 hr 3-1/2 hr 1/2 hr 2-1/2 hr 1/4 hr 1/4 hr 5-1/2 hr 1 hr 1/4hr 1-3/4 hr 1/2 hr 3 hr lhr 1-1/2 hr 3 hr lhr 1/4 hr 1-3/4 hr 1/2 hr 1 hr 1 hr 9-1/2 hr 1/2 hr 7-1/2 hr 1/4 hr 1-1/4 hr 1 hr 1/4 hr 1 hr 1/4 hr Activity Held safety meeting Drilled to 10589.00 ft Flow check Pulled out of hole to 0.00 ft Pulled BHA Tested BOP stack Made up BHA no. 16 R.I.H. to 3000.00 ft Held drill (Kick while tripping) R.I.H. to 5000.00 ft Held safety meeting R.I.H. to 10589.00 ft Drilled to 10643.00 ft Circulated at 10643.00 ft Flow check Held drill (H2S) Pulled out of hole to 0.00 ft Pulled BHA Held safety meeting Made up BHA no. 17 R.I.H. to 6100.00 ft Held drill (H2S) R.I.H. to 10643.00 ft Drilled to 10670.00 ft Functioned downhole tools at 10670.00 ft Drilled to 10796.00 ft Held safety meeting Drilled to 10891.00 ft Held drill (Spill) Circulated at 10891.00 ft Drilled to 11085.00 ft Circulated at 11085.00 ft Flow check Pulled out of hole to 8600.00 ft Held safety meeting Pulled out of hole to 0.00 ft Pulled BHA Made up BHA no. 18 R.I.H. to 8500.00 ft Serviced Block line Held drill (Fire) R.I.H. to 9525.00 ft Held safety meeting R.I.H. to 11085.00 ft Circulated at 11085.00 ft Drilled to 11140.00 ft Held safety meeting Drilled to 11176.00 ft Flow check Pulled out of hole to 9535.00 ft Functioned downhole tools at 9350.00 ft Flow check Pulled out of hole to 8850.00 ft Held drill (Kick while tripping) Facility Date/Time 10 Feb 97 11 Feb 97 12 Feb 97 13 Feb 97 PB G Pad 18:00-18:30 18:30-21:00 21:00-22:00 22:00-00:30 00:30-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-16:30 16:30-16:45 16:45-17:00 17:00-18:00 18:00-18:30 18:30-21:30 21:30-22:00 22:00-22:30 22:30-02:30 02:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-09:30 09:30-09:45 09:45-14:30 14:30-16:00 16:00-18:00 18:00-18:30 18:30-19:00 19:00-02:00 02:00-02:30 02:30-05:30 05:30-06:00 06:00-09:30 09:30-13:30 13:30-15:00 15:00-15:30 15:30-18:00 18:00-18:30 18:30-19:00 19:00-22:00 22:00-22:30 22:30-23:00 23:00-23:30 23:30-00:00 00:00-06:00 06:00-12:00 12:00-13:30 13:30-18:00 18:00-18:30 18:30-19:00 19:00-20:00 20:00-23:30 23:30-01:30 Duration 1/2 hr 2-1/2 hr 1 hr 2-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 9-1/2 hr 1/4 hr 1/4 hr 1 hr 1/2 hr 3 hr 1/2 hr 1/2 hr 4 hr 3-1/2 hr 1/2 hr 1 hr 1 hr 1 hr 1/4 hr 4-3/4 hr 1-1/2 hr 2 hr 1/2 hr 1/2 hr 7 hr 1/2 hr 3 hr 1/2 hr 3-1/2 hr 4 hr 1-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 3 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 6 hr 6 hr 1-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1 hr 3-1/2 hr 2 hr Progress Report Well G-32A Rig Doyon 16 Activity Held safety meeting Pulled out of hole to 0.00 ft Downloaded MWD tool Made up BHA no. 19 R.I.H. to 10438.00 ft Functioned downhole tools at 10438.00 ft Circulated at 11176.00 ft Held safety meeting Functioned downhole tools at 11176.00 ft Drilled to 11237.00 ft Flow check Held drill (Spill) Pulled out of hole to 9028.00 ft Held safety meeting Pulled out of hole to 0.00 ft Pulled BHA Made up BHA no. 20 Functioned downhole tools at 250.00 ft R.I.H. to 9014.00 ft Held safety meeting R.I.H. to 11237.00 ft Functioned downhole tools at 11237.00 ft Circulated at 11241.00 ft Flow check Pulled out of hole to 0.00 ft Pulled BHA Serviced Subs Held safety meeting Made up BHA no. 21 Tested M.W.D. tool - Via string Made up BHA no. 21 R.I.H. to 9125.00 ft Circulated at 9125.00 ft Tested MWD - Via string Pulled out of hole to 83.00 ft Serviced M.W.D. tool Made up BHA no. 23 Tested MWD - Via string Held safety meeting Made up BHA no. 23 R.I.H. to 9132.00 ft Tested M.W.D. tool - Via string R.I.H. to 11158.00 ft Took MWD survey at 11188.00 ft Tested GR - Via string Drilled to 11375.00 ft Drilled to 11536.00 ft Circulated at 11536.00 ft Pulled out of hole to 2965.00 ft Held safety meeting Pulled out of hole to 149.00 ft Pulled BHA Tested BOP stack Made up BHA no. 24 Page Date 6 22 May 97 Facility Date/Time 14 Feb 97 15 Feb 97 16 Feb 97 17 Feb 97 18 Feb 97 PB G Pad 01:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-10:30 10:30-12:30 12:30-14:30 14:30-15:00 15:00-20:30 20:30-21:30 21:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-10:30 10:30-11:30 11:30-14:30 14:30-01:30 01:30-03:00 03:00-04:30 04:30-06:00 06:00-06:30 06:30-08:00 08:00-13:30 13:30-14:30 14:30-16:30 16:30-17:30 17:30-18:30 18:30-19:00 19:00-02:00 02:00-06:00 06:00-06:30 06:30-09:00 09:00-11:30 11:30-12:00 12:00-13:00 13:00-13:30 13:30-15:00 15:00-16:00 16:00-17:00 17:00-17:30 17:30-18:00 18:00-20:30 20:30-01:00 01:00-03:00 03:00-03:30 03:30-05:30 05:30-06:00 06:00-07:30 07:30-08:00 08:00-14:30 14:30-18:00 18:00-18:30 Duration 3hr 1 hr 1/2 hr 1/2 hr 1 hr 3 hr 2 hr 2 hr 1/2 hr 5-1/2 hr lhr 7-1/2 hr 1 hr 1/2 hr 1/2 hr 3-1/2 hr lhr 3hr llhr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 5-1/2 hr 1 hr 2 hr lhr 1 hr 1/2 hr 7 hr 4hr 1/2 hr 2-1/2 hr 2-1/2 hr 1/2 hr lhr 1/2 hr 1-1/2 hr lhr 1 hr 1/2 hr 1/2 hr 2-1/2 hr 4-1/2 hr 2 hr 1/2 hr 2 hr 1/2 hr 1-1/2 hr 1/2 hr 6-1/2 hr 3-1/2 hr 1/2 hr Progress Report Well G-32A Page 7 Rig Doyon 16 Date 22 May 97 Activity R.I.H. to 9110.00 ft Serviced Block line Tested MWD - Via string Tested MWD - Via string R.I.H. to 11536.00 ft Drilled to 11565.00 ft Circulated at 11565.00 ft Drilled to 11595.00 ft Took MWD survey at 11595.00 ft Pulled out of hole to 64.00 ft Pulled BHA Made up BHA no. 25 Made up BHA no. 25 Held safety meeting Made up BHA no. 25 R.I.H. to 9250.00 ft Took MWD survey at 9250.00 ft Washed to 11595.00 ft Drilled to 12220.00 ft Circulated at 12220.00 ft Pulled out of hole to 9169.00 ft R.I.H. to 12220.00 ft R.I.H. to 12220.00 ft Circulated at 12220.00 ft Pulled out of hole to 422.00 ft Pulled BHA Rigged up Tubing handling equipment Rigged up Top ram Tested Top ram Held safety meeting Ran Liner to 3800.00 ft (2-7/8in OD) Ran Tubing to 3725.00 ft (1-1/4in OD) Held safety meeting Ran Tubing to 3725.00 ft (1-1/4in OD) Ran Drillpipe in stands to 7500.00 ft Rigged up Cement head Ran Drillpipe in stands to 9100.00 ft Circulated at 9100.00 ft Ran Drillpipe in stands to 12220.00 ft Circulated at 12220.00 ft Mixed and pumped slurry - 35.510 bbl Displaced slurry - 33.280 bbl Set Liner hanger at 8418.00 ft with 0.0 psi Circulated at 12125.00 ft Pulled Drillpipe in stands to 3725.00 ft Laid down 1636.00 ft of Tubing Circulated at 2089.00 ft Laid down 2089.00 ft of Tubing Rigged up Top ram Rigged up Top ram Tested Liner Rigged up sub-surface equipment - Gun assembly Ran Tubing to 3767.00 ft (1-1/4in OD) Held safety meeting Facility PB G Pad Progress Report Well G-32A Rig Doyon 16 Page Date 8 22 May 97 Date/Time 19 Feb 97 20 Feb 97 18:30-23:00 23:00-00:00 00:00-00:30 00:30-01:30 01:30-06:00 06:00-06:30 06:30-08:30 08:30-12:00 12:00-12:30 12:30-18:00 18:00-18:30 18:30-19:30 19:30-23:30 23:30-03:00 03:00-06:00 06:00-08:00 08:00-10:00 10:00-12:00 Duration 4-1/2 hr 1 hr 1/2 hr lhr 4-1/2 hr 1/2 hr 2 hr 3-1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 1 hr 4 hr 3-1/2 hr 3 hr 2 hr 2 hr 2 hr Activity Ran Drillpipe in stands to 12125.00 ft Perforated Flow check Circulated at 10735.00 ft Laid down 8336.00 ft of 2-3/8in OD drill pipe Held safety meeting Laid down 2100.00 ft of 2-3/8in OD drill pipe Laid down 3767.00 ft of Tubing Held safety meeting Laid down 1366.00 ft of Tubing Held safety meeting Ran Drillpipe in stands to 3290.00 ft Laid down 3290.00 ft of 2-3/8in OD drill pipe Rigged down BOP stack Tested Tubing head spool Rigged up Chicksan lines Installed Lubricator Rig moved 0.00 % S~ BP EXPLORATION PBU / G-32A 500292163601 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/27/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 9110.00 8727.99 8663.85 9120.15 8737.05 8672.91 9151.94 8764.87 8700.73 9184.14 8792.47 8728.33 9215.90 8819.26 8755.12 9251.21 8848.62 8784.48 9283.63 8875.18 8811.04 9315.54 8900.06 8835.92 9346.73 8921.16 8857.02 9378.56 8939.19 8875.05 9408.03 8953.82 8889.68 9426.34 8961.88 8897.74 9459.12 8974.24 8910.10 9490.12 8983.89 8919.75 9519.66 8991.24 8927.10 9551.09 8996.96 8932.82 9582.80 9000.61 8936.47 9614.61 9002.47 8938.33 9646.44 9002.97 8938.83 9678.30 9002.27 8938.13 9707.30 9000.90 8936.76 9740.37 8998.59 8934.45 9772.05 8996.90 8932.76 9801.23 8997.13 8932.99 9830.50 8998.05 8933.91 9862.02 8998.60 8934.46 9893.80 8999.38 8935.24 9923.59 9000.68 8936.54 9962.64 9002.31 8938.17 9994.23 9004.41 8940.27 10025.90 9007.66 8943.52 10056.90 9011.06 8946.92 10088.64 9014.60 8950.46 10120.23 9017.41 8953.27 10150.60 9017.44 8953.30 RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE DATE OF SURVEY: 021697 MWD SURVEY JOB NUMBER: AK-Mw-70018 KELLY BUSHING ELEV. = 64.14 OPERATOR: BP EXPLORATION FT. COURS INCLN DG MN COURSE DLS 'TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 25 43 N 19.00 E .00 1883.50N 103.90E 27 47 N 18.98 E 20.49 1887.82N 105.39E 30 6 N 16.04 E 8.51 1902.49N ll0.00E 31 53 N 13.10 E 7.30 1918.54N 114.16E 33 5 N 6.90 E 11.14 1935.33N l17.11E 497.84 497.80 498.07 499.20 501.73 34 24 N 2.20 E 8.26 1954.87N 118.65E 35 35 N 2.70 E 3.81 1973.45N 119.44E 42 5 N 9.90 W 31.99 1993.32N 118.04E 52 42 N 17.90 W 38.83 2015.50N 112.41E 58 24 N 28.00 W 31.68 2039.58N 102.13E 506.45 511.58 519.20 531.57 548.95 62 17 N 42.20 W 43.88 2060.42N 87.41E 65 35 N 30.80 W 58.74 2073.62N 77.66E 70 5 N 30.40 W 13.77 2099.75N 62.21E 73 35 N 29.90 W 11.39 2125.22N 47.42E 77 35 N 30.80 W 13.86 2149.90N 32.97E 569.51 582.93 605.86 627.95 649.48 81 24 N 30.70 W 12.09 2176.46N 17.17E 85 24 N 32.10 W 13.35 2203.33N .76E 87 54 N 33.70 W 9.33 2229.99N 16.49W 90 18 N 34.80 W 8.29 2256.30N 34.40W 92 11 N 35.60 W 6.47 2282.32N 52.76W 672.87 696.95 721.75 747.07 772.72 93 13 N 37.50 W 7.43 2305.59N 70.00W 94 48 N 37.80 W 4.86 2331.71N 90.15W 91 18 N 42.20 W 17.73 2355.93N 110.48W 87 48 N 45.80 W 17.20 2376.91N 130.74W 88 35 N 48.90 W 10.93 2396.73N 152.26W 796.45 823.83 850.78 876.65 903.33 89 24 N 53.00 W 13.25 2416.58N 176.73W 87 48 N 57.70 W 15.62 2434.64N 202.85W 87 11 N 61.00 W 11.25 2449.81N 228.45W 88 0 N 63.60 W 6.96 2467.94N 263.00W 84 24 N 63.10 W 11.50 2482.08N 291.16W 932.82 963.33 992.41 1030.92 1062.11 83 48 N 64.60 W 5.08 2495.96N 319.44W 83 35 N 66.50 W 6.13 2508.71N 347.48W 83 35 N 69.80 W 10.33 2520.45N 376.76W 86 11 N 73.10 W 13.27 2530.46N 406.58W 93 41 N 74.60 W 25.18 2538.90N 435.73W 1093.33 1123.97 1155.45 1186.91 1217.23 SP tY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION PBU / G-32A 500292163601 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/27/97 DATE OF SURVEY: 021697 MWD SURVEY JOB NUMBER: AK-MW-70018 KELLY BUSHING ELEV. = 64.14 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10183.85 9014.86 8950.72 10215.80 9012.38 8948.24 10247.42 9010.83 8946.69 10279.17 9009.48 8945.34 10310.71 9007.58 8943.44 95 11 93 41 91 54 93 0 93 54 N 76.60 W 7.50 2547.14N 467.83W N 79.90 W 11.32 2553.63N 499.01W N 82.00 W 8.74 2558.59N 530.20W N 80.80 W 5.12 2563.33N 561.56W N 80.20 W 3.43 2568.53N 592.61W 1250.29 1281.92 1313.07 1344.32 1375.42 10341.21 9005.48 8941.34 94 0 10373.56 9003.25 8939.11 93 54 10405.20 9001.07 8936.93 94 0 10433.54 8999.27 8935.13 93 18 10465.19 8997.91 8933.77 91 35 N 79.80 W 1.35 2573.81N 622.57W N 79.80 W .31 2579.53N 654.34W N 79.40 W 1.30 2585.23N 685.38W N 79.40 W 2.47 2590.43N 713.18W N 79.60 W 5.41 2596.19N 744.27W 1405.52 1437.45 1468.71 1496.72 1528.04 10496.82 8997.72 8933.58 89 5 10528.37 8999.21 8935.07 85 30 10559.85 9001.68 8937.54 85 30 10591.00 9003.87 8939.73 86 25 10641.00 9007.02 8942.88 86 20 N 80.30 W 8.21 2601.71N 775.41W N 80.30 W 11.41 2607.02N 806.47W N 81.10 W 2.53 2612.09N 837.44W N 80.66 W 3.30 2617.02N 868.12W N 80.01 W 1.31 2625.39N 917.31W 1559.32 1590.47 1621.45 1652.11 1701.42 10691.00 9010.21 8946.07 86 10741.00 9013.42 8949.28 86 10791.00 9016.61 8952.47 86 10841.00 9019.92 8955.78 86 10891.00 9023.57 8959.43 85 20 18 22 2 35 N 80.48 W .94 2633.85N 966.49W N 80.41 W .15 2642.13N 1015.69W N 79.86 W 1.10 2650.68N 1064.85W N 80.14 W .87 2659.34N 1113.98W N 80.70 W 1.43 2667.64N 1163.15W 1750.74 1800.04 1849.38 1898.72 1947.99 10941.00 9027.47 8963.33 85 26 10999.00 9031.95 8967.81 85 41 11031.21 9034.12 8969.98 86 35 11062.86 9036.08 8971.94 86 18 11094.50 9038.04 8973.90 86 35 N 80.14 W 1.15 2675.94N 1212.31W N 80.00 W .48 2685.91N 1269.27W N 79.60 W 3.08 2691.60N 1300.89W N 79.70 W 1.00 2697.28N 1331.97W N 79.40 W 1.34 2703.00N 1363.02W 1997.24 2054.43 2086.23 2117.50 2148.77 11125.00 9039.87 8975.73 11156.60 9041.97 8977.83 11182.10 9043.88 8979.74 11214.27 9046.04 8981.90 11245.77 9047.91 8983.77 86 30 85 54 85 30 86 48 86 24 N 74.10 W 17.35 2709.98N 1392.65W N 76.30 W 7.20 2718.03N 1423.13W N 76.60 W 1.96 2723.99N 1447.85W N 78.40 W 6.89 2730.93N 1479.18W N 80.70 W 7.40 2736.64N 1510.09W 2179.08 2210.54 2235.88 2267.79 2298.93 11277.39 9049.20 8985.06 88 54 11307.94 9049.90 8985.76 88 30 11339.59 9050.53 8986.39 89 11 11371.20 9050.25 8986.12 91 48 11402.85 9049.04 8984.90 92 35 N 80.50 W 7.93 2741.80N 1541.25W N 79.70 W 2.93 2747.05N 1571.34W N 80.60 W 3.60 2752.46N 1602.52W N 80.50 W 8.23 2757.65N 1633.69W N 82.40 W 6.51 2762.35N 1664.96W 2330.12 2360.32 2391.60 2422.82 2453.97 SP7 IY-SUN DRILLING SERVICES ANCHOP~AGE ALASKA PAGE 3 BP EXPLORATION PBU / G-32A 500292163601 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/27/97 DATE OF SURVEY: 021697 MWD SURVEY JOB NUMBER: AK-MW-70018 KELLY BUSHING ELEV. = 64.14 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11434.53 9047.35 8983.21 93 30 N 83.40 W 4.24 2766.26N 1696.35W 2484.98 11466.15 9045.70 8981.56 92 30 N 84.40 W 4.47 2769.62N 1727.75W 2515.83 11494.40 9044.39 8980.25 92 48 N 86.20 W 6.45 2771.93N 1755.87W 2543.23 11528.55 9042.64 8978.50 93 5 N 85.90 W 1.24 2774.28N 1789.89W 2576.25 11560.23 9041.23 8977.09 92 0 N 85.90 W 3.47 2776.54N 1821.46W 2606.91 11591.72 9039.88 8975.74 92 54 N 85.90 W 2.86 2778.79N 1852.84W 2637.38 11623.32 9038.28 8974.14 92 54 N 85.80 W .32 2781.07N 1884.32W 2667.97 11654.79 9036.69 8972.55 92 54 N 85.70 W .32 2783.40N 1915.66W 2698.43 11686.60 9035.00 8970.86 93 11 N 82.90 W 8.84 2786.56N 1947.27W 2729.41 11717.68 9033.67 8969.53 91 41 N 86.10 W 11.36 2789.53N 1978.17W 2759.67 11749.29 9032.73 8968.59 91 41 N 85.20 W 2.85 2791.93N 2009.67W 2790.31 11780.91 9031.85 8967.71 91 30 N 84.80 W 1.42 2794.68N 2041.16W 2821.05 11812.43 9031.02 8966.88 91 30 N 85.50 W 2.22 2797.35N 2072.56W 2851.67 11843.99 9030.20 8966.06 91 30 N 85.40 W .32 2799.85N 2104.0tW 2882.29 11875.96 9029.44 8965.30 91 11 N 84.50 W 2.97 2802.66N 2135.84W 2913.38 11907.55 9028.98 8964.84 90 30 N 84.40 W 2.24 2805.72N 2167.28W 2944.17 11939.18 9028.59 8964.45 90 54 N 84.10 W 1.58 2808.89N 2198.75W 2975.02 11969.52 9028.09 8963.95 91 0 N 83.40 W 2.33 2812.19N 2228.90W 3004.67 12001.12 9027.53 8963.39 91 0 N 83.40 W .06 2815.82N 2260.29W 3035.59 12032.73 9026.96 8962.82 91 5 N 83.20 W .71 2819.51N 2291.68W 3066.53 12064.36 9026.32 8962.18 91 11 N 83.00 W .71 2823.31N 2323.07W 3097.52 12095.62 9025.77 8961.63 90 48 N 83.50 W 2.05 2826.98N 2354.11W 3128.12 12127.24 9025.33 8961.19 90 48 N 83.10 W 1.26 2830.67N 2385.51W 3159.07 12158.86 9024.89 8960.75 90 48 N 82.90 W .63 2834.52N 2416.89W 3190.06 12179.10 9024.59 8960.45 90 54 N 83.60 W 3.49 2836.90N 2436.99W 3209.88 12220.00 9023.88 8959.74 91 5 N 85.10 W 3.70 2840.93N 2477.68W 3249.75 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3769.58 FEET AT NORTH 41 DEG. 5 MIN. WEST AT MD = 12220 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 288.46 DEG. TIE-IN SURVEY AT 9,110.00' MD WINDOW POINT AT 9,120.15' MD PROJECTED SURVEY AT 12,220.00' MD SI 'RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 BP EXPLORATION PBU / G-32A 500292163601 NORTH SLOPE BOROUGH COMPUTATI ON DATE: 2 / 27 / 97 INTERPOLATED VALUES FOR EVEN 1000 DATE OF SURVEY: 021697 JOB NUMBER: AK-MW-70018 KELLY BUSHING ELEV. = 64.14 OPERATOR: BP EXPLORATION FEET OF MEASURED DEPTH FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 9110.00 8727.99 8663.85 1883.50 N 103.90 E 382.01 10110.00 9016.66 8952.52 2527.40 N 396.85 W 1093.34 711.33 11110.00 9038.96 8974.82 2706.21 N 1378.16 W 2071.04 977.70 12110.00 9025.57 8961.43 2828.61 N 2368.40 W 3084.43 1013.39 12220.00 9023.88 8959.74 2840.93 N 2477.68 W 3196.12 111.70 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S~ ~tY-SUN DRILLING SERVICES .... ANCHORAGE ALASKA PAGE 5 BP EXPLORATION PBU / G-32A 500292163601 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/27/97 DATE OF SURVEY: 021697 gOB NUMBER: AK-MW-70018 KELLY BUSHING ELEV. = 64.14 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVID VERTICAL DIFFERENCE CORRECTION 9110.00 8727.99 8663.85 1883.50 N 103.90 E 382.01 9151.10 8764.14 8700.00 1902.10 N 109.88 E 386.96 4.95 9270.05 8864.14 8800.00 1965.55 N 119.07 E 405.91 18.95 9431.99 8964.14 8900.00 2078.07 N 75.02 E 467.85 61.94 12220.00 9023.88 8959.74 2840.93 N 2477.68 W 3196.12 2728.27 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS D I~ I I--I--I N (~ ~ EE FI~/I r- El S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 May 21, 1997 RE: MWD Formation Evaluation Logs G-32A, AK-MW-70018 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 995] 8 2" x 5" MD Gamma Ray Logs: 50-029-21636-01 2"x 5" TVD Gamma Ray Logs: 50-029-21636-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company M,EMORAN D. .,VI TO: THRU: State Alaska Alaska Oil and Gas Conservation Commission David Johns~, Chairma~,~~ Blair Wondzeii, P. I. Supervisor DATE: January 30, 1997 FILE NO: ahika4ee.doc FROM: Chuck Scheve, ~ ~ SUBJECT: Petroleum Inspector BOPE Test Doyon 16 PBU G-3ZA PTD # 97-01 Thumdav January 30, 1997: I traveled to BPX's G-32A Well being drilled by Doyon Rig 16 and witnessed the weekly BOPE test. As the attached AOGCC BOPE test report shows the test lasted 2.5 hours with 2 failures. The Methane gas detectors at the shaker and the cellar failed to test. Both of the failed detector heads were replaced and retested later in the day. The test went well with good test procedures being employed by the Doyon crews. The rig was clean and all related equipment appeared to be in good working order. The location was well organized allowing good access to the rig. Summary: I witnessed the weekly BOPE on Doyon rig 16 test time 2.5 hours 2 failures. Attachment: ahika4ee.xls X' Unclassified Confidential Confidential (Unclassified if doc. removed ) STATE OF ALASKA r~ ~ ~ OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drig Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: DATE: Doyon Rig No. 16 PTD # g7-01 Rig Ph.# BPX Rep.: Dink Helm 1/30/g7 659-4610 G-32A Rig Rep.: WaYne Stotts Set@ Location:Sec. 12 T. 11N R. 13E Meridian Weekly X Other ' Umiat Well Sign OK Drl. Rig OK Hazard Sec. OK FLOOR SAFETY VALVES: Quan. Pressure P/F Lower Kelly / IBOP --1 250/5,000 [ P . Ball Type 1 250/5~ P Inside BOP 1 250/5,~.. .. ~ ' MISC. INSPECTIONS: Location Gen.: OK Housekeeping: oK '(Gen) PTD On Location Yes Standing Order Posted Yes BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1 HCR Valves Kill Une Valves Check Valve Test Press. Test 250/2~ Pressure 250/5,~ 250/5,000 250/5,000 250/5,000 250/5,000 PtF P CHOKE MANIFOLD: P No. Valves 13 ,i P No. Flanges 26 'p ' Manual Chokes f. p- Hydraulic Chokes I I FuncEoned Functioned P/F P P P P 2 250/5,000 P I 250/5, 000 P ACCUMULATOR SYSTEM: N/A N/A N/A System Pressure 2900 ! . Pressure After Closure 2100 I MUD SYSTEM: Visual Alarm 200 psi Attained After Closure . minutes 12 sec. Trip Tank OK OK System Pressure Attained ._.--- minutes 55 . sec. Pit Level Indicators OK OK Blind Switch Covers: Master: OK Remote: OK Flow Indicator OK OK Nitgn. Btl's: 6 ~ 2000 PSI Meth Gas Detector F/P F/P Psig. ,,, H2S Gas Detector P P Number of Failures: 2 ,Test Time: 2.5 Hours. Number of valves tested 2f Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. i. Supervisor at 279-1433 Ill I II III I I I I I II REMARKS: The Methane Gas Detectors at the shakers and the celler were not working. These we~ repaired and tested. ~ Distribution: odg-Well File c - Oper./Rig c - Database c - Tdp Rpt File c - Inspector STATE VVITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Wrtnessed By: Chuck Scheve FIA321 L (Rev. 12/94) AHIKA4EE.XLS TONY KNOWLE$, GOVERNOR ALASK& OIL ~ GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Januars,' 8, 1997 Paul Prince Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 R¢~ Prudhoe Bay Unit G-32A BP Exploration (Alaska) Inc. Permit No. 97-01 Sur. Loc. 2299'SNL, 2369'WEL. Sec. 12, T11N, R13E. UM Btnmholc Loc. 448'NSL, 4682'WEL, Sec. 1, T11N, RI3E, UM Dear Mr. Prince: Enclosed is the approvcd application for permit to rcdrill the above rcfcrcnccd well. The permit to redrill docs not cxcmpt you from obtaining additional permits required by lax,,' from other governmcntal agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. Blowout prcvcntion cquipmcnt (BOPE) must be tested in accordancc with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of thc Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission pctrolcum field inspector on thc North Slope pagcr at 659-3607. Chairman ~ "~ BY ORDER OF THE COMMISSION dlf/Enclosurcs CC; Dcpartmcnt of Fish & Game, Habitat Scction ~v/o cncl. Department of Environmcntal Conservation w/o cncl. STATE OF ALASKA ALASKA ~L AND GAS CONSERVATION COmmISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill I lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen~ [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 60.25' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028280 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2299' SNL, 2369' WEL, SEC. 12, T11N, R13E, UPM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 340' NSL, 3364' WEL, SEC. 1, T11N, R13E, UPM G-32A At total depth 9. Approximate spud date Amount $200,000.00 448' NSL, 4682' WEL, SEC. 1, T11N, R13E, UPM 01/10/97 12. Distance to nearest property line113. Distance to nearest well 114. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028304, 4682'I No Close Approach 2560 11944' MD / 8950' TVD 16. To be completed for deviated wells ;17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 9120' MD Maximum Hole Angle 90° Maximum surface 3300 psig, At total depth (TVD) 8800' / 3900 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4# L-80 ST-L 3643' 8300' 7910' 11944' 8950' 155 sx Class 'G' ' '""~','~.,,! V ~/..,/ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary JAN 0 2 i997 Total depth: measured 9610 feet Plugs (measured) true vertical 9175 feet Effective depth: measured 9562 feet Junk (measured) true vertical 9133 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 9 cu yds 145' 145' Surface 2647' 13-3/8" 3723 cu ft 2682' 2682' Intermediate 8744' 9-5/8" 875 cu ft 8779' 8428' Production Liner 1081' 7" 413 cu ft 8529'- 9610' 8196'- 9175' Perforation depth: measured 9371'- 9391', 9401'- 9421', 9430'- 9440' true vertical subsea 8891' - 8953' (three intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling F~luid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/l~u~nber: Ti~h~urns, 564-4315 Prepared By Name/Number: Terrie Hubble, 564-4628 I/ 21. I hereby certify that the f/~/Ceg~n~j~ Ir/u/e and. d.~correct to the best of my knowledge Signed ~L~/,. ~...~~ PauIPrince /,,,,¢"-'~ ~ Title Senior Drilling Engineer Date Commission Use Only PermitNumber I APINumber I Ap~_~ovalDate I Seecoverletter ~',/~ - O// 50-43 ~ ~' - ~ / ~' .-~ ~' - o ,) / ~' -- ~:' '~' for other requirements Conditions of Approval: Samples Required [] Yes "~ No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures ~Yes [] No Directional Survey Required ~ Yes [] No Required Working Pressure for DOPE [] 2M; []3M; ~ 5M; [] 10M; [] 15M Other: df¢..~lR8~ Signed By by order of Approved By ~_-.::[.,!. W..Iohnst0n Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate [Well Name: IG-32A I TTRD Sidetrack Plan Summary Type of Redrill (producer or injector): I Shut In Producer I Surface Location: 2299' FNL, 2369' FEL, S12, TI iN, R13E, UM Target Location: 340' FSL, 3364' FEL, Si, T11N, R13E, UM Bottom Hole Location: 448' FSL, 4682' FEL, S1, TllN, R13E, UM [AFENumber: 14P0881 I I Estimated Start Date: I 1/10/97 IMD: 111944 I Rig: I Doyon 16 [ [ [Operating days to complete: 120 I ITVD: 18950ss I IRKB 160'25' I I Well Design (conventional, slimhole, etc.): I Through tubing horizontal sidetrack [Objective: l Zone 1 Mud Program Drilling Fluids I 9.0 ppg BARADRILn (solids free) Density LSRV PV Chlor. pH Lubetex Biocide K:N SOLIDS ppg C.P.G. (CP) mg/L Concen. Ratio (%) 9.0 40,000 8 40,000 8.5 1.0% +100 ppm 2.4 <1.0% to to to to to to to to to 9.0 50,000 10 40,000 9.0 3.0% +100 ppm 1 <1.0% Directional [ KOP: I _+9,120' MD (estimated) I Maximum Hole Angle: I +90° Close Approach Well: none Casing/Tubing Program Hole Size Csg Wt/Ft Grade Conn Length Top Btm MD/TVDss MD/TVDss 3-3/4" 2-7/8 6.4 L-80 ST-L 3643' 8300'/7910 11944'/8950' Cement [Liner Size: 12-7/8" [ Bas,s:[ 50% open hole excess, 80 shoe joint, _300 MD above the KOP ms,de of casing. [ Total Cement Volume: [ 155 sx[ Class G Blend (Yield = 1.19 fff/sk) G-32A Drilling Permit Page 2/2 Well Control Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Hazards Sadlerochit pressure is +3,900 psi at 8,800' TVDss or +8.5 ppg EMW. No other hazards are expected. Operational Summary 1. MIRU drilling rig. Pull BPV. ND tree, NU and test BOPE. 3. Mill window in 7" liner at +9,120' MD (Zone 2). Dress window with 2nd mill run if necessary. Directionally drill 3-3/4" hole to 11,944' MD per attached directional plan. POOH. Run and cement 2-7/8", 6.4#, STL, L-80 liner with 2-7/8" x 4-1/2" hanger/packer landed inside 4-1/2" tubing at +8,300' MD. Test liner and liner top to 2,500 psi. POOH and lay down liner running equipment. Perforate liner via DPC perforating guns. POOH. Install TWC, ND BOP, NU and test tree. Freeze protect wellbore to _+2,000' MD. RDMO drilling rig. . . o o , o t. Structure: PB G P°d . Well: G-32A Field: Prudhoe Boy Location · Alaska For Permitting Only I Checked "'/"~'~.~.zT(. _. -~~-- AP P r°v e d/~,~'~' ~'"~'~-~--- .... Point .... T~e on End of Build KOP End of Build --nd of Hold target [arget WELL PROFILE DATA MD Inc Dir TVD North East DLS(de§/lOOfO 9110 25.72 18.98 8728 1883 104 0.00 9136 26.00 18.00 8751 1894 107 2.00 9550 88~0 502.00 8983 2134 -73 20.00 9633 88.95 306.99 8985 2181 -141 6.00 10082 88.95 306.99 8993 2451 -500 0.00 10621 89.57 274.65 9000 2640 -997 6.00 11944 89.56 274.67 9010 2747 -2315 0.00 7600 - .. 8000 - -- -,- 8400 - - -- u 8800 - ._ ~ 9200 - -- II 9600 - v 10000 - 10400 I .,:% ° o, -400 0 400 800 1200 1600 2000 2400 2800 5200 5600 Scale 1 ' 400.00 Vertical Section on 288.46 azimuth with reference 0.00 N, 0.00 E from 32A N TRUE HORTH For Perm,~j~g Only Checked ::-~~_~__~ I Approved./__,/-__~.~-~ ~ Shared Services Drill n Structure · PB G Pad Well ' G-32A Field · Prudhoe Bay Location · Alaska WELL PROFILE DATA .... Point .... MD Inc Dir Tie on 9110 25.72 18.98 End of Build 9136 26.00 18.00 KOP 9550 88.90 302.00 End of Build 9633 88.95 306.99 End of Hold 10082 88.95 306.99 Target 10621 89.57 274.65 Target 11944 89.56 274.67 1'VD No~h East DLS(deg/lOOff) 8728 1883 104 0.00 8751 1894 107 2.00 8983 2134 -73 20.00 8985 2181 -141 6.00 8993 2451 -500 0.00 9000 2640 -997 6.00 9010 2747 -2315 0.00 Scale1'400.00 E C~ St ~ ~ d/5, N OZ ]991 _ ooo _ oo 3600 I I I I I I I I I I I I I I I I I 3600 052A ESL Z BSL I I I I I I I I I I I I 3200 - -- 2800 - -- (~ 2400 - ' I ' L - O 2000- -- °° 1600 - .. '~ 1200 - ,5200 -- - 2800 -- - 2400 -- - 2000 -- - 1 600 -- 1 200 -3000 -2600 -2200 -1800 -1400 -1000 -600 -200 200 600 A II · oo.oo East G-32A Wp4 Vertical Section RKB 288.46 60.25' MD Inc. Azi. TVDss TVDrkb Rect. Coordinates Northing 9110.00 25.72 18.98 8667.74 8727.99 1883.47n 9135.53 26.00 18.00 8690.71 8750.96 1894.03n 9200.00 31.18 353.08 8747.50 8807.75 1924.16n 9300.00 45.21 329.57 8826.31 8886,56 1981.04n 9400.00 62.06 316.05 8885.57 8945.82 2044.07n 9500.00 79.86 306.35 8918.13 8978.38 2105.67n 9550.12 88.90 302.00 8923.04 8983.29 2133.64n ~600.00 88.93 304.99 8923.99 8984.24 2161.16n 9633.34 88.95 306.99 8924.60 8984.85 2180.75n 9700.00 88.95 306.99 8925.83 8986.08 2220.85n 9800.00 88.95 306.99 8927.66 8987.91 2281.02n 9900.00 88.95 306.99 8929.50 8989.75 2341.18n 10000.00 88.95 306.99 8931.33 8991.58 2401.34n 10082.24 88.95 306.99 8932.84 8993.09 2450.82n 10100.00 88.96 305.93 8933.16 8993.41 2461.37n 10200.00 89.06 299.93 8934.89 8995.14 2515.70n 10300.00 89.17 293.93 8936.43 8996.68 2560.96n 10400.00 89.29 287.93 8937.78 8998.03 2596.66n 10500.00 89.41 281.93 8938.92 8999.17 2622.41n 10600.00 89.54 275.93 8939.83 9000.08 2637.93n 10621.36 89.57 274.65 8940.00 9000.25 2639.90n 10700.00 89.57 274.65 8940.59 9000.84 2646.27n 10800.00 89.57 274.65 8941.34 9001.59 2654.38n '3900.00 89.57 274.65 8942.09 9002.34 2662.50n .,i~O00.O0 89.57 274.66 8942.85 9003.10 2670.61n 11100.00 89.57 274.66 8943.60 9003.85 2678.73n 11200.00 89.57 274.66 8944.36 9004.61 2686.85n 11300.00 89.57 274.66 8945.11 9005.36 2694.98n 11400.00 89.57 274.66 8945.87 9006.12 2703.11n 11500.00 89.57 274.66 8946.63 9006.88 2711.24n 11600.00 89.57 274.67 8947.39 9007.64 2719.37n 11700.00 89.56 274.67 8948.14 9008.39 2727.51n 11800.00 89.56 274.67 8948.90 9009.15 2735.65n 11900.00 89.56 274.67 8949.67 9009.92 2743.79n 11943.91 89.56 274.67 8950.00 9010.25 2747.37n Easting 103.89e 107.43e 109.79e 88.49e 39.36e 31.66w 72.88w 114.47w 141.44w 194.67w 274.52w 354.38w 434.23w 499.91w 514.19w 598.07w 687.18w 780.53w 877.10w 975.84w 997.11w 1075.49w 1175.16w 1274.83w 1374.49w 1474.16w 1573.83w 1673.49w 1773.16w 1872.83w 1972.49w 2072.16w 2171.82w 2271.49w' 2315.25w Grid Coordinates Easting 657916.43 657919.74 657921.48 657898.99 657848.57 657776.28 657734.49 657692.35 657664.98 657610.93 657529.84 657448.76 657367.67 657300.99 657286.49 657201.50 657111.48 657017.41 656920.33 656821.3O 656800.00 656721.51 656621.70 656521.89 656422.08 656322.28 656222.47 656122.66 656O22.86 655923.05 655823.24 655723.44 655623.63 655523.83 655480.00 Northing 5971226.71 5971237.34 5971267.52 5971323.93 5971385.93 5971446.03 5971473.13 5971499.78 5971518.80 5971557.78 5971616.27 5971674.75 5971733.23 5971781.33 5971791.58 5971844.15 5971887.54 5971921.29 5971945.02 5971958.47 5971960.00 5971964.74 5971970.78 5971976.81 5971982.85 5971988.89 5971994.94 5972000.99 5972007.04 5972013.09 5972019.15 5972025.21 5972O31.27 5972037.34 5972040.00 DLS deg/100ft 0.00 2.00 20.00 20.00 20.00 20.00 20.00 6.00 6.00 0.00 0.00 0.00 0.00 0.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section 497.84 497.83 505.13 543.35 609.91 696.78 744.73 792.89 824.68 887.87 982.67 1077.46 1172.26 1250.22 1267.11 1363.88 1462.73 1562.58 1662.34 1760.91 1781.70 1858.07 1955.18 2052.29 2149.40 2246.51 2343.62 244O.73 2537.84 2634.95 2732.07 2829.18 2926.29 3023.41 3066.05 G32A BSL G32A ESL Comment 12/26/96 4:35 PM Page 1 of 1 STATE OF ALASKA ALASKA . AND GAS CONSERVATION COk.._ iSSION APPLi~'ATION FOR SUNDRY APPR~'VAL i. Type of Request: [] Abandon I-I Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing f-I Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 2299' SNL, 2369' WEL, SEC. 12, T11N, R13E, UPM At top of productive interval 507' SNL, 2302' WEL, SEC. 12, T11N, R13E, UPM At effective depth 224' SNL, 2220' WEL, SEC. 12, T11N, R13E, UPM At total depth 202' SNL, 2216' WEL, SEC. 12, T11N, R13E, UPM 12. Present well condition summary Total depth: measured 9610 feet true vertical 9175 feet Effective depth: measured 9562 feet true vertical 9133 feet Casing Length Structural Conductor 110' Surface 2647' Intermediate 8744' Production Liner 1081' Plugs (measured) Junk (measured) Size Cemented 6. Datum Elevation (DF or KB) KBE: 72.25' AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number G-32 9. Permit Number 86-146 10. APl Number 50-029-21636 11. Field and Pool Prudhoe Bay Field/Prudhoe Bay Pool MD TVD 20" 9 cu yds 145' 145' 13-3/8" 3723 cu ft 2682' 2682' 9-5/8" 875 cuft 8779' 8428' 7" 413 cu ft 8529' - 9610' 8196' - 9175' Perforation depth: measured 9371'-9391', 9401'-9421', 9430'-94.40' RECEIVED true vertical subsea 8891'- 8953' (three intervals) DI~C ,~ 01996 Tubing (size, grade, and measured depth) 4-1/2", L-80 to 8470' with 4-1/2" tailpipe to 858~1~.~1~ 011 & G~ ~ns. Comm~mn Anchorage Packers and SSSV (type and measured depth) 9-5/8" TIW packer at 8470'; 4-1/2" SSSV at 2087' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 4. Estimated date for commencing operation January 1, 1997 16. If proposal was verbally approved Name of approver /' Contact Engineer Nam¢/~ 17. I hereby certify that tlC¢'f Signed A(~L Paul Prince 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Date approved ~/umber:. ~l~n' Burns, 564-4315 Prepared By Name/Number: %~correct to the best of my knowledge// Terrie Hubble, 564-4628 Title Senior Drilling Engineer Commission Use Only Conditions of Approval: Notify Commiss, io,g so representative may witness Plug integrity ,,,~- BOP Test __ Location clearance __ Mechanical Integrity Test .. Subsequent form required 10- Original Signea By Approved by order of the Commission David W. Johnston AP~t~_s_~-~ R~r Form 10-403 Rev. 06/15/88 J-t{DtLUl lll~U . I Approval No.~9~,- ~/-/q' Date Submit In Triplicate · FIELD & POOL ADMINISTRATION WELL PERMIT CHECKLIST 1 1 APPR 1 · · INIT CLASS ~/~..~ ENGINEERING ..... GEOLAREA 1. Permit fee =~ed ....................... I.~Y~, 2. Lease number appropriate .................... Y ,) 3. Unique we~ name and number ................. Ii) N 4. Well Ioc~ in a defined Pool .................. N 5. Well located proper distance from ddg unit boundary .... N other 6. Well located proper distance from we~s ........ i Y N 7. Sufficient acreage available in ddlfing un~. .......... N 8. If deviated, is wellbore plat included N ~. o~,- ~ ~:,,:~ p,:~ ..... ~ ~ ~ ~ ~ ~ ~ ~'. ~ ~ ~ ~ ~.,.,Y N 0. Operator has appropriate bond in force ............ IYI N 1. Permit can be issued without conservation order ...... ~ N 2. Permit can be issued wil~ administrative approvaJ .... N 3. Can permit be approved before 15-day wa~ ........ N ....... PROGRAM: UNIT# /'/~/~' <"_~ ON/OFF SHORE REMARKS .... GEOLOGY ' 14. Conductor s~ing provided ................... Y N 15. Surface ca..~ng protects all known USDWs .......... Y N 16. CMT vol adequate to circulate on conductor & sud csg .... Y N 17. CMT vol adequate to fie-in long string to surf csg ....... Y 18. CMT will cover all known produc~e horizons. ........ ~)..~N 19. Casing designs adequate for C, T, B & ~ ..... .,,~Y~N 20. Adequate tankage or reserve piL ............... (...Y/' N 21. If a re-drilL has a 10-403 for abndnmnt been approved.., i~ N 22. Adequate wellbore separation proposed ........... N 23. If diverter required, is it adequate. '.~ ~,J,~r' 25. BOPEs adequate ....................... ./rY~ N 26. BOPE press rating adequate; test to ~ psig.~N 27. Choke mar~fold complies w/APl RP-53 (May 84) ....... ~.~ ~. Work will occur without operatbn shutdown ......... ..~/N 29. is presence of H2S gas probable .Y~ N 30. Permit can be issued w/o hydrogen sulfide measures ..... Y/~ ./~ N//~,~)N 31. Da~ presented on potential overpre..~ure zones ....... Y 32. Seismic analysis of shallow gas zones ............ .~ N ' 33. Seabed condition survey (if off-shore) .......... ~.. Y N 34. Comact name/phone for weekl~ progress reports ....~.... Y N le. xptoratory only] GEOLOGY: ENGINEERING: ~P~~ ~Ew~ ,/~ JDH~ JDN TAB ~-~.k%..,'-.--~/'' Comments/Instructions: HOW~I~- A.'~-OR~st rev ~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. .. Sperry-Sun Drilling Services LIS Scan Utility Thu Jun 19 10:59:21 1997 Reel Header Service name ............. LISTPE Date ..................... 97/06/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/06/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: Date_ MWD RUN 2 AK-AK-70018 S. NEUBAUER D. HEIM JUi' 2 0 1997 Ai~.~.~. ~i & Gas 0orm. Commission Anchorage G-32A 500292Z6360Z BP EXPLO~TION (A~S~) , INC. SPERRY-SUN DRILLING SERVICES 19-~N-97 MWD RUN 4 AK-AK-70018 S. NEUBAUER D. HEIM MWD RUN 6 AK-AK-70018 S. NEUBAUER D. HEIM JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 AK-AK-70018 S. NEUBAUER D. HEIM MWD RUN 8 AK-AK-70018 S. NEUBAUER D. HEIM MWD RUN 9 AK-AK-70018 S. NEUBAUER D. HEIM JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 10 AK-AK-70018 S. NEUBAUER D. HEIM MWD RUN 11 AK-AK-70018 S. NEUBAUER D. HIEM MWD RUN 12 AK-AK-70018 S. NEUBAUER D. HIEM JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 13 AK-AK-70018 S. NEUBAUER D. HIEM MWD RUN 14 AK-AK-70018 W. JACKSON D. HIEM MWD RUN 16 AK-AK-70018 W. JACKSON D. HI EM JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 19 AK-AK-70018 A. WORTHINGT M. JACKSON 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: File Header MWD RUN 20 AK-AK-70018 A. WORTHINGT M. JACKSON 12 liN 13E 2299 2369 64.10 62.60 34.70 MWD RUN 21 AK-AK-70018 A. WORTHINGT M. JACKSON OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 4.500 8589.0 7.000 9122.0 12220.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUN 15 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2,4,6,7,8,9,10,11,12,13,14,16,19,20, AND 21 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGp) . 5. MWD RUNS 1,3,5,17, AND 18 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). THESE RUNS CONTAIN NO VALID DATA AND ARE NOT PRESENTED. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM D. DOUGLAS OF BP EXPLORATION (ALASKA), INC ON MAY 14, 1997. 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12221'MD, 9024'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Conmaent 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 GR 9088.5 ROP 9129.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 12174.5 12221.0 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE MWD 2 9129. MWD 4 9267. MWD 6 9484. MWD 7 9725. MWD 8 9931. MWD 9 9958 MWD 10 9985 MWD 11 10108 MWD 12 10188 MWD 13 10588 MWD 14 10644 MWD 16 11179. MWD 19 11237. MWD 20 11538. MWD 21 11595. $ REMARKS: MERGED MAIN PASS. $ TOP MERGE BASE 0 9267.0 0 9484.0 0 9725.0 0 9931.0 0 9958.0 0 9985.0 0 10108.0 0 10188.0 0 10588.0 0 10644.0 0 11085.0 0 11237.0 0 11538.0 0 11595.0 0 12221.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9088.5 12221 10654.8 6266 9088.5 ROP 2.78 1517.74 72.4281 6185 9129 GR 17.51 317.68 50.4484 6121 9088.5 Last Reading 12221 12221 12174.5 First Reading For Entire File .......... 9088.5 Last Reading For Entire File ........... 12221 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 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 ....... 97/06/19 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9088.5 9227.5 ROP 9129.0 9267.0 $ LOG HEADER DATA DATE LOGGED: 26-JAN-97 SOFTWARE SURFACE SOFTWARE VERSION: 1.32 DOWNHOLE SOFTWARE VERSION: 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9267.0 TOP LOG INTERVAL (FT) : 9129.0 BOTTOM LOG INTERVAL (FT) : 9267.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINII~UM ANGLE: 27.8 MAXIMUM ANGLE: 33.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE ~qD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : TOOL NUMBER NGP 320 3.750 3.8 BARADRI L 8.60 50.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.7 24500 8.6 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 63.0 First Name Min Max Mean Nsam Reading DEPT 9088.5 9267 9177.75 358 9088.5 GR 17.63 54.19 22.7254 279 9088.5 ROP 11.78 136.37 42.3704 277 9129 Last Reading 9267 9227.5 9267 First Reading For Entire File .......... 9088.5 Last Reading For Entire File ........... 9267 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9222.5 9452.5 ROP 9255.5 9484.0 $ LOG HEADER DATA DATE LOGGED: 27-JAN-97 SOFTWARE SURFACE SOFTWARE VERSION: 1.32 DOWNHOLE SOFTWARE VERSION: 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9484.0 TOP LOG INTERVAL (FT) : 9267.0 BOTTOM LOG INTERVAL (FT): 9484.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 33.5 MAXIMUM ANGLE: 77.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 323 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: BARADRI L 8.60 51.0 9.0 26000 7.4 .000 .000 .000 .000 58.6 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STAlqDOFF (IN) : .3 EWR FREQUENCY REMARKS: $ (HZ): Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Refe Frame Spa Max frame Absent va Depth Uni Datum Spe fence Point .............. Undefined cing ..................... 60 .liN s per record ............. Undefined lue ...................... -999.25 ts ....................... cification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9222.5 9484 9353.25 524 9222.5 GR 17.51 108.68 28.1323 461 9222.5 ROP 4.44 337.14 63.4529 458 9255.5 Last Reading 9484 9452.5 9484 First Reading For Entire File .......... 9222.5 Last Reading For Entire File ........... 9484 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Lecord..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FI LE SUp~V~XRY VENDOR TOOL CODE START DEPTH GR 9375.0 ROP 9423.0 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9678.0 9724.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMYIA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMlvI) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPEtLATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... 29-JAN-97 1.32 5.74 MEMORY 9725.0 9484.0 9725.0 65.6 92.2 TOOL NUMBER NGP 323 3.750 3.8 BARADRI L 8.60 57.0 8.7 26000 6.3 .000 .000 .000 .000 63.3 .3 Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 ]LAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9375 9724.5 9549.75 700 9375 GR 30.36 133.38 51.6452 607 9375 ROP 2.78 120.72 34.108 604 9423 Last Reading 9724.5 9678 9724.5 First Reading For Entire File .......... 9375 Last Reading For Entire File ........... 9724.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9681.5 9898.0 ROP 9690 . 5 9929 . 5 $ LOG HEADER DATA DATE LOGGED: 31-JAN-97 SOFTWARE SURFACE SOFTWARE VERSION: 1.32 DOWNHOLE SOFTWARE VERSION: 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9931.0 TOP LOG INTERVAL (FT) : 9725.0 BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9931.0 87.7 95.0 TOOL NUMBER NGP 320 3.750 3.8 BARAD RI L 8.70 56.0 8.6 26000 5.6 .000 .000 .000 .000 63.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9681.5 9929.5 9805.5 497 9681.5 GR 30.02 139.1 58.2486 434 9681.5 ROP 8.18 4346.42 306.378 479 9690.5 Last Reading 9929.5 9898 9929.5 First Reading For Entire File .......... 9681.5 Last Reading For Entire File ........... 9929.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9898.5 9925.0 ROP 9931.5 9956.5 $ LOG HEADER DATA DATE LOGGED: 31-JAN-97 SOFTWARE SURFACE SOFTWARE VERSION: 1.32 DOWNHOLE SOFTWARE VERSION: 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9958.0 TOP LOG INTERVAL (FT) : 9931.0 BOTTOM LOG INTERVAL (FT) : 9958.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.2 MAXIMUM ANGLE: 299.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : TOOL NUMBER NGP 194 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 BARADRI L 8.70 59.0 8.6 25000 5.4 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 65.6 First Name Min Max Mean Nsam Reading DEPT 9898.5 9956.5 9927.5 117 9898.5 GR 50.21 88.28 65.2006 54 9898.5 ROP 11.42 87.43 49.4926 51 9931.5 Last Reading 9956.5 9925 9956.5 First Reading For Entire File .......... 9898.5 Last Reading For Entire File ........... 9956.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9914.0 ROP 9962.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM]ANGLE: STOP DEPTH 9937.5 9984.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 01-FEB-97 1.32 5.74 MEMORY 9985.0 9958.0 9985.0 .0 .0 TOOL NUMBER NGP 328 3.750 3.8 BARADRI L 8.70 55.0 8.5 27000 5.6 .000 .000 .000 .000 65.5 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA~NDOFF (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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 AAPI 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9914 9984.5 9949.25 142 9914 GR 57.87 78.85 68.1348 48 9914 ROP 11.91 67 35.8091 45 9962.5 Last Reading 9984.5 9937.5 9984.5 First Reading For Entire File .......... 9914 Last Reading For Entire File ........... 9984.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9941.0 ROP 9985.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10067.0 10108.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: M/3D CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 03-FEB-97 1.32 5.74 MEMORY 10108.0 9985.0 10108.0 83.6 88.0 TOOL NUMBER NGP 328 3.750 3.8 BARADRI L 8.70 58.0 8.5 27500 5.8 .000 .000 .000 .000 63.0 .3 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 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 GR MWD 10 AAPI 4 1 68 4 2 ROP MWD 10 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9941 10108 10024.5 335 9941 GR 33.2 72.69 48.8268 253 9941 ROP 3.89 275.75 39.569 246 9985.5 Last Reading 10108 10067 10108 First Reading For Entire File .......... 9941 Last Reading For Entire File ........... 10108 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Corament Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10068.5 10144.0 ROP 10112.5 10187.0 $ LOG HEADER DATA DATE LOGGED: 04-FEB-97 SOFTWARE SURFACE SOFTWARE VERSION: 1.32 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5.74 MEMORY 10188.0 10108.0 10188.0 83.7 86.2 TOOL NUMBER NGP 320 3.750 3.8 BARADRI L 8.70 58.0 8.5 27500 5.8 .000 .000 .000 .000 154.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 11 AAPI 4 1 68 4 2 ROP MWD 11 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading Last Reading DEPT 10068.5 10187 10127.8 238 GR 28.67 150.9 64.3924 152 ROP 19.46 1083.11 117.392 150 10068.5 10068.5 10112.5 10187 10144 10187 First Reading For Entire File .......... 10068.5 Last Reading For Entire File ........... 10187 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10144.5 10545.0 ROP 10189.0 10587.0 LOG HEADER DATA DATE LOGGED: 06-FEB-97 SOFTWARE SURFACE SOFTWARE VERSION: 1.32 DOWNHOLE SOFTWARE VERSION: 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 10588.0 TOP LOG INTERVAL (FT): 10188.0 BOTTOM LOG INTERVAL (FT): 10588.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.5 MAMIMUM ANGLE: 95.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL G~ PROBE TOOL NUMBER NGP 29 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.750 3.8 Baradril 8.70 58.0 8.2 26000 5.8 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 12 AAPI 4 1 68 4 2 ROP MWD 12 FT/H 4 1 68 8 3 158.0 First Name Min Max Mean Nsam Reading DEPT 10144.5 10587 10365.8 886 10144.5 GR 27.98 146.24 44.506 802 10144.5 ROP 6.77 159 47.4095 797 10189 Last Reading 10587 10545 10587 First Reading For Entire File .......... 10144.5 Last Reading For Entire File ........... 10587 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10546.0 ROP 10590.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10600.5 10643.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHI~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 06-FEB-97 1.32 5.74 MEMORY 10644.0 10588.0 10644.0 85.5 86.5 TOOL NUMBER NGP 29 3.750 3.8 Baradril 8.70 55.0 8.8 27500 5.6 .000 .000 .000 162.0 MUD CAKE AT MT: .000 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 13 A_API 4 1 68 4 2 ROP MWD 13 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DE?T 10546 10643.5 10594.8 196 10546 GR 32.52 41.95 37.7212 110 10546 ROP 18.92 1517.74 79.2344 108 10590 Last Reading 10643.5 10600.5 10643.5 First Reading For Entire File .......... 10546 Last Reading For Entire File ........... 10643.5 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUmmARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10602.0 10848.5 ROP 10644.5 10890.5 $ LOG HEADER DATA DATE LOGGED: 08-FEB-97 SOFTWARE SURFACE SOFTWARE VERSION: 1.32 DOWNHOLE SOFTWARE VERSION: 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 11085.0 TOP LOG INTERVAL (FT) : 10644.0 BOTTOM LOG INTERVAL (FT): 11085.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL NUMBER NGP 328 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 3.750 3.8 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Baradril 8.70 63.0 8.2 28000 5.2 .000 .000 .000 .000 72.6 .3 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 ...................... -999.25 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 GR MWD 14 AAPI 4 1 68 4 2 ROP MWD 14 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10602 10890.5 10746.2 578 10602 GR 28.98 136.3 44.7919 494 10602 ROP 29.35 595.74 60.8037 493 10644.5 Last Reading 10890.5 10848.5 10890.5 First Reading For Entire File .......... 10602 Last Reading For Entire File ........... 1089~.5 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.013 Physical EOF File Header Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.012 Comment Record FILE HEADER FILE NUMBER: 13 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 16 DEPTH INCREMENT: .5000 FILE SUl~MARY VENDOR TOOL CODE GR ROP $ START DEPTH STOP DEPTH 10849.0 11162.0 10891.0 11236.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 10-FEB-97 1.32 5.74 MEMORY 11237.0 11179.0 11237.0 85.6 85.9 TOOL NUMBER NGP 315 3.750 3.8 Baradril 8.70 58.0 8.4 28000 5.6 .000 .000 .000 .000 72.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 16 AAPI 4 1 68 4 2 ROP MWD 16 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 10849 11236.5 11042.8 776 GR 26.37 115.74 55.7642 627 ROP 5.85 446.17 67.0544 692 First Reading 10849 10849 10891 Last Reading 11236.5 11162 11236.5 First Reading For Entire File .......... 10849 Last Reading For Entire File ........... 11236.5 File Trailer Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.014 Physical EOF File Header Service name ............. STSLIB.014 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.013 Corament Record FILE HEADER FILE NUMBER: 14 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 19 DEPTH INCREMENT: .5000 FILE SUNm{ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11164.0 11464.0 ROP 11238.5 11538.0 $ LOG HEADER DATA DATE LOGGED: 13-FEB-97 SOFTWARE SURFACE SOFTWARE VERSION: 1.32 DOWNHOLE SOFTWARE VERSION: 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 11538.0 TOP LOG INTERVAL {FT) : 11237.0 BOTTOM LOG INTERVAL (FT) : 11538.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ~GLE: 85.5 MJ~MIMUM ~qGLE: 93.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE ~D CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER NGP 317 3.750 3.8 Baradril 8.70 53.0 8.2 27500 6.0 .000 .000 .000 .000 77.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 19 AAPI 4 1 68 4 2 ROP MWD 19 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11164 11538 11351 749 11164 GR 32.83 223.08 68.592 601 11164 ROP 7.59 655.79 78.2342 600 11238.5 Last Reading 11538 11464 11538 First Reading For Entire File .......... 11164 Last Reading For Entire File ........... 11538 File Trailer Service name ............. STSLIB.014 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.015 Physical EOF File Header Service name ............. STSLIB.015 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.014 Comment Record FILE HEADER FILE NUMBER: 15 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 20 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11490.5 11547.0 ROP 11497.5 11594.5 $ LOG HEADER DATA DATE LOGGED: 14-FEB-97 SOFTWARE SURFACE SOFTWARE VERSION: 1.32 DOWNHOLE SOFTWARE VERSION: 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : ~11595.0 TOP LOG INTERVAL (FT): 11538.0 BOTTOM LOG INTERVAL (FT): 11595.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 92.5 MJtXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : TOOL NUMBER NGP 315 3.750 3.8 Baradril 8.60 60.0 8.8 27000 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION TOOL STANDOFF (IN): EWR FREQUENCY (HZ): (IN) : 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 20 AAPI 4 1 68 4 2 ROP MWD 20 FT/H 4 1 68 8 3 72.1 First Name Min Max Mean Nsam Reading DEPT 11490.5 11594.5 11542.5 209 11490.5 GR 66.53 317.68 137.361 114 11490.5 ROP 13.98 1764.35 337.447 195 11497.5 Last Reading 11594.5 11547 11594.5 First Reading For Entire File .......... 11490.5 Last Reading For Entire File ........... 11594.5 File Trailer Service name ............. STSLIB.015 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.016 Physical EOF File Header Service name ............. STSLIB.016 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB. 015 Comment Record FILE HEADER FILE NUMBER: 16 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 21 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11549.0 ROP 11596.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12174.5 12221.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: I~TRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 16-FEB-97 1.32 5.74 MEMORY 12221.0 11595.0 12221.0 90.5 93.2 TOOL NUMBER NGP 317 3.750 3.8 Baradril 8.60 57.0 9.0 27500 5.4 .000 .000 .000 .000 72.1 .3 $ 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 21 AAPI 4 t 68 ROP MWD 21 FT/H 4 1 68 Code Offset 0 4 8 Channel 1 2 3 Name Min Max Mean DEPT 11549 12221 11885 GR 26.24 173.4 44.8439 ROP 15.58 567.83 137.849 Nsam 1345 1252 1250 First Reading 11549 11549 11596.5 Last Reading 12221 12174.5 12221 First Reading For Entire File .......... 11549 Last Reading For Entire File ........... 12221 File Trailer Service name ............. STSLIB.016 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.017 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/06/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/06/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File
