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196-137
WELL COMPLETION OR RECOMPLETION REPORT AND LOG 866 sx CS III, 177 sx G, 250 sx CS II By Meredith Guhl at 9:48 am, Apr 25, 2022 Abandoned 4/7/2022 MDG RBDMS 4/25/2022 MDG DLB 04/27/2022MGR18AUG2022 xG DSR_4/25/22 4.22.2022 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.04.22 13:13:23 -08'00' Monty M Myers ACTIVITYDATE SUMMARY 2/16/2022 ***WELL S/I ON ARRIVAL*** (pre ctd) UNABLE TO LATCH PATCH @ 11,717' MD. BAILED ~4 GALLONS OF SCALE FROM TOP OF PATCH @ 11,717' MD. ***WSR CONTINUED ON 2/17/22*** 2/17/2022 ***WSR CONTINUED FROM 2/16/22*** (pre ctd) BAILLED ~3/4 GALLON OF SCALE FROM TOP OF PATCH @ 11,717' MD. PULLED 4-1/2" UPPER PATCH SECTION FROM 11,695' SLM. PULLED 4-1/2" MIDDLE PATCH SECTION FROM 11,732' SLM. ***WSR CONTINUED ON 2/18/22*** 2/18/2022 T/I/O= 1700/1380/N/A assist slickline (LOAD & TEST) pumped 122 bbls crude down IA. pumped 105 bbls crude down TBG. ***job continued on 2-19-22*** 2/18/2022 ***WSR CONTINUED FROM 2/17/22*** (ctd) PULLED 4-1/2" LOWER PATCH SECTION FROM 11,745' SLM. DRIFTED TO 11,874' SLM w/ 20' x 3.70" DUMMY WHIPSTOCK. RAN READ 40 ARM CALIPER FROM 11,874' SLM TO SURFACE. T-BIRD LOADS IA w/ 122 bbls, TBG w/ 101 bbls CRUDE. SET 4-1/2" PX-PLUG w/ FILL EXT IN X-NIP @ 5,977' MD. ***WSR CONTINUED 2/19/22*** 2/19/2022 ***WSR CONTINUED FROM 2/18/22*** (Pre - CTD) T-BIRD ATTEMPTS 3,200 psi MIT-T. (TxIA communication) T-BIRD PERFORMS PASSING 3,200 psi TxIA CMIT PULL INT-OGLV FROM ST# 2 @ 5,795' MD SET INT-DGLV IN ST# 2 @ 5,795' MD T-BIRD PERFORMS PASSING 3,200psi MIT-T PULL INT-DGLV FROM ST# 2 5,795' MD SET INT-OGLV IN ST# 2 5,795' MD PULL CATCHER FROM TOP OF PRONG @ 5,938' SLM PULL PX PLUG FROM X-NIPPLE @ 5,977' MD ***WELL S/I ON DEPARTURE*** 2/19/2022 ***job continued from 2-18-22*** CMIT-TxIA***PASS*** to 3390/3270. pumped 2bbls crude to reach max applied 3500psi with a target psi of 3200. 1st 15 min TxIA lost 80/75. 2nd 15 min TxIA lost 30/30. total loss of 110/105psi.bleed back14.3 bbls. M.I.T.-T ***PASS*** at 3475/200 pumped 10 BBLS to achieave M.A.P. of 3500 with target of 3250 1st 15 min TBG lost 100 PSI 2nd 15 min TBG lost 25 PSI, TOTAL loss of 125 PSI. Bled TBG back to Starting pressure of 500 PSI bleeding back 4 BBLS Slickline in control of well upon departure FWHP= 500/200 3/12/2022 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(set cibp) RIH W/ BAKER 4-1/2" CIBP. SET TOP OF CIBP AT 11819'. CCL TO TOP OF CIBP OFFSET: 12.1'. CCL STOP DEPTH: 11806.9'. CORRELATED TO HES PRODUCTION PROFILE DATED 7-OCT-2021. ...JOB CONT ON 13-MAR-2022... 3/12/2022 Assist ELine (CTD) Pumped 180 bbls 1% KCL, 2 bbls 60/40 meth and 41 bbls DSL down IA for load and FP. Pumped 320 bbls 1%KCL, 2 bbls 60/40 meth and 34 bbls DSL down Tbg for FP. Freeze Protected FL w/ 6 bbls 60/40 meth and pressured up FL to 1500 psi. Eline in control of well per LRS departure. IA,OA=OTG Daily Report of Well Operations PBU P1-06 Daily Report of Well Operations PBU P1-06 3/13/2022 ...CONT FROM 12-MAR-2022 WSR...(whipstock) RIH W/ 4-1/2" MONOBORE BAKER WHIPSTOCK SET TOWS AT 11800'. CCL TO TOWS OFFSET: 20.1'. CCL STOP DEPTH: 11779.9'. TOWS ORIENTATED TO 0 DEG HIGHSIDE. ***JOB COMPLETE, LEFT S/I. READY FOR COIL*** Activity Date Ops Summary 4/5/2022 Move both modules together down K-pad road to P1-06. Rig modules arrive P1 pad. Remove jeeps, lay composite mats. Spot drilling module and set it down. Spot pit module and set it down Accept rig at 22:30. Start MIRU checklists. Hook up interconnect lines. Get steam going around rig. Put stairs down. About 1500 psi on well. Inflow test on SV, MV (independently) is good. Remove tree cap, install BOPs. Grease choke valves. 4/6/2022 Continue MIRU Check List Fluid Pack Surface lines and stack. Shell test BOPE. Good Shell Test. Test BOPE to 250psi Low and 3500 psi High. Test Witness waived by Lou Laubenstein. Test #1 IRV, Stripper, C7, C9, C10, C11 - Pass. Test #2 B/S, R2, BL2, C15 - Pass. Test #3 Annular 2-3/8", TIW #1, B1, B4 - Pass Test #4 Upper 2-3/3* P/S, TIW #2, B2, B3 - Pass. Test #5 Lower 2-3/8" P/S, C5, C6, C8, TV2 - Fail, TV1 leaking a the flange, tighten flange and retest. Retest #5 Lower 2-3/8" P/S, C5, C6, C8, TV2 - Pass. Test #6 Choke A, Choke C - Pass. Draw Down Test - Pass. Test Gas Alarms Test #7 C1, C4, TV1 - Fail, C4 leak, grease and retest. Retest #7 C1, C4, TV1 - Pass. Test #8 3" P/SC2,C3 - Pass. BOP Test. Completed, RD test equipment. RU to test check valves. PT to 4000 psi. Good. Test BHI connections to 5000 psi. Good MU BHA #1 - 3" JSN and stinger and stab on well. Wind direction blowing directly from return tank to rig. Discuss bullhead kill options with Drilling Engineer. Open well to kill down managed pressure line. T/I = 1542/1068. Line up and pump 10 bbls MeOH down well. 1 bpm @ 1500 psi. Pump 1% slick KCL down tubing. 4.6 bpm @ 1550 psi and slowly climbing. 40 bbls pumped and pressure = 1760 psi. Bring additional rig generator online and increase rate to 5 bpm. Continue bullhead well kill. 75 bbls away. 5 bpm @ 2140 psi. 115 bbls away. 5 bpm @ 2070 psi. 135 bbls away drop rate to 4 bpm briefly to stay under 2500 psi. 165 bbls away. 5 bpm @ 1700 psi. 180 bbls away. 5 bpm @ 2200 psi and climbing. 190 bbls away. 4 bpm @ 2453 psi. Continue bullhead kill operations. 250 bbls away 4 bpm @ 2500 psi. Perform injectivity tests: 1 bpm = 1300 psi. .5 bpm = 900 psi. .25 bpm = 600 psi. Total of 260 bbls KCL pumped. Swap to 8.7 ppg PowerPro mud system. 4.2 bpm @ 2456 psi. Drop rate @ 180 bbls away to 3.4 bpm and 2400 psi. Pump total of 190 bbls PowerPro down tubing. Displace coil to PowerPro. Shut down and flow check well. No flow. Fluid at surface. Break injector off well. Inspect and service injector. MU Baker window milling BHA w/3.80" string reamer and 3.80"mill. RIH w/BHA #2 - window milling BHA. In Rate = 1 bpm Out Rate = 1.45 bpm. MW In = 8.78ppg MW Out = 8.76. Circ pressure = 1311 psi. IA = 1131psi. Log Tie-In from 11,500'. 4/7/2022 RIH to 11500 and log tie. -29' correction, RIH. Tag WS at 11802'. PU, online with pumps at 2.082 bpm at 3250 psi free spin Motor work at 11801.3' start milling window. 2.84 BPM MWD Diff Psi = 415 psi. In Rate = 2.84 bpm, Out Rate = 2.81 bpm. MWT In = 8.77 ppg, MWO = 8.7 ppg, WOB = 1.7k. WHP = 47 psi (open choke) 9.94 ECD at the window. Milled to 11804.3'. 2.74 BPM MWD Diff Psi = 415 psi. In Rate = 2.77 bpm, Out Rate = 2.78 bpm. MWT In = 8.74 ppg, MWO = 8.7 ppg, WOB = 4.25k. WHP = 50 psi (open choke) 9.94 ECD at the window Continue milling window from 11807.5'. MWD Diff Psi = 493 psi. In Rate = 2.80 bpm, Out Rate = 2.81 bpm. MW In = 8.74 ppg, MW Out = 8.76 ppg, WOB = 3.4k. WHP = 53 psi (open choke) 9.94 ECD at the window. Appear to exit window at 11808.8' Mill rat hole from 11808.8'. MWD Diff Psi = 700 psi. In Rate = 2.79 bpm, Out Rate = 2.80 bpm. MW In = 8.74 ppg, MW Out = 8.76 ppg, WOB = 2.7k. WHP = 53 psi (open choke) 9.95 ECD at the window. ROP = 10 fph. Confirm 75% formation sand in bottoms up sample. Complete drilling rat hole to 11819'. Backream through window at 1 fpm. Slight motor work at 11802' noted during reaming pass. Repeat reaming pass and dry drift without any issue. Dry tag @ 11819.6'. POOH for lateral BHA. Paint white EOP flag @ 11600' (11722' bit depth). In Rate = 2.77 bpm, Out Rate = 2.81 bpm. MW In = 8.72 ppg, MW Out = 8.76 ppg OOH - Flow check well and confirm no flow. Rig back injector and LD window milling BHA. Mill and Reamer both gauge 3.80" Go 3.79" No/Go. MU build BHA with 4.25" bi- center bit. RIH w/BHA #3 Build BHA. In Rate = .96 bpm, Out Rate = 1.49 bpm. MW In = 8.75 ppg, MW Out = 8.77 ppg. WHP = 14 psi, IA = 1145 psi Log Tie-In pass from 11500' @ 5 fpm. Correct - 27'. Close EDC and RIH through window. Tag @ 11,819' PU and establish drilling parameters. In Rate = 2.79 bpm, Out Rate = 2.81 bpm. MW In = 8.75 ppg, MW Out = 8.78 ppg. WHP = 60 psi, IA = 1147 psi. Begin drilling build from 11819'. 50-029-22695-01-00API #: Well Name: Field: County/State: PBE P1-06A Prudhoe Bay East Hilcorp Energy Company Composite Report , Alaska 4/7/2022Spud Date: Tag WS at 11802'. 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PTM P1-06 Set tubing patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 196-137 50-029-22695-00-00 12183 Conductor Surface Intermediate Production Liner 9148 80 6004 6322 11906 20" 7" 4-1/2" 8935 36 - 116 35 - 6039 5861 - 12183 36 - 116 35 - 4944 4824 - 9148 11990 , 11992 1500 5410 7500 11906 3060 7240 8430 11730 - 12028 4-1/2" 12.6# 13CR NSTC 33 - 5859 8800 - 9029 Structural 5" Baker ZXP LTP 5861 5861 4824 Bo York Operations Manager Kirsty Glasheen Kirsty.Glasheen@hilcorp.com 907.564.5258 PRUDHOE BAY, PT MCINTYRE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0034624 No SSSV 33 - 4823 4824 371 402 21746 18085 4855 4046 1596 1894 1022 1387 n/a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: By Samantha Carlisle at 10:15 am, Nov 22, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.11.22 07:39:52 -09'00' Bo York RBDMS HEW 11/24/2021 MGR29DEC2021 DSR-11/22/21SFD 11/29/2021 ACTIVITYDATE SUMMARY 10/2/2021 **WELL FLOWING ON ARRIVAL** DRIFT w/ 4 1/2" BLB & 3.75" GUAGE RING TO 9945'MD (unable to work deeper, work tools from 7336'slm) RAN 3.69" BROACH TO 11875'SLM RAN 3.74" BROACH TO 11881'SLM DRIFTED w/ DUMMY 45KB TO 11750'SLM (sd in multiple places, 1150# pu weight @ depth) **JOB CONT ON 10/3/21** 10/3/2021 **JOB CONT'D FROM 10/2/21** RAN 3.77" BROACH TO CIBP @ 11906'MD (broached hard scale from 9000' to 10400'slm) LRS PUMPED 260BBLS SLICK CRUDE DRIFTED w/ 38'x3.70" DUMMY PATCH DRIFT TO CIBP @ 11906'MD (pumped down from 4000' to 5500'slm) **WELL S/I ON DEPARTURE, TURNED OVER TO DSO** 10/3/2021 Assist Slickline (PROFILE MODIFICATION) Pumped 150 bbls crude w/ 776 down Tbg for load. Pumped 134 bbls crude w/ 776 down Tbg while SL broached. Pumped 6 bbls DSL down Tbg to pump down SL. SL in control of well per LRS departure. IA=OTG 10/7/2021 ***WELL FLOWING ON ARRIVAL*** (Pprof) MIRU HES E-LINE PERFORM PPROF PER PROGRAM. DYNAMIC PASSES 30/60/90/120 FPM FROM 11650' - 11905' STATION SURVEYS AT 11700', 11809', 11858', 11905'. RDMO E-LINE. ***WELL FLOWING ON DEPARTURE*** 10/25/2021 Freeze Protect Flowline (slickline) Pump 5 bbls 60/40 down Flowline, S=C,W=C,SSV=C,MV=O IA=OTG,OA=OTG, Slickline in control of well upon departure 10/25/2021 ***WELL ONLINE ON ARRIVAL, DSO NOTIFIED***(set 45kb patch) SET BH 45 FLOGARD LOWER PKR PATCH ASSEMBLY @ MID-ELEMENT AT 11798' CCL TO ME OFFSET: 45.5'. CCL STOP DEPTH: 11752.5'. (SPECS OF SECTION LEFT IN THE HOLE = 37.96' OAL / 2.37" ID) (EST. TOP OF THIS SECTION @ 11765') CORRELATED TO SLB PPROF DATED: 02-MAR-2008. ***TURN WELL OVER TO DSO, LEFT S/I ON DEPARTURE*** 11/6/2021 ***WELL S/I ON ARRIVAL*** (profile modification) SET 4-1/2" MIDDLE PATCH SECTION @ 11751' MD (14.57' oal) SET 4-1/2" UPPER PATCH SECTION w/ 45 FLOGARD PKR @ 11716' MD (ME) (35.82' oal) **PU WEIGHT OVER 1950# BEFORE SETTING** ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED OF STATUS*** Daily Report of Well Operations PBU P1-06 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/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?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 ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU P1-06 Mill Window Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 196-137 50-029-22695-00-00 ADL 028297 & 034624 12183 Conductor Surface Intermediate Production Liner 9148 80 6005 6322 11906 20" 7" 4-1/2" 8935 35 - 115 34 - 6039 5861 - 12183 3020 36 - 115 35 - 4944 4824 - 9148 unknown, 11992 1500 5410 7500 11906 3060 7240 8430 11730 - 12028 4-1/2" 12.6#13Cr80 30 - 58648800 - 9029 Structural No Packer No SSSV Installed No Packer No SSSV Installed Date: Monty Myers Drilling Manager Trevor Hyatt trevor.hyatt@hilcorp.com 777-8396 PRUDHOE BAY, PT MCINTYRE OIL February 1, 2022 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 10/2021 Approved application is valid for 12 months from the date of approval. 11.16.2021 By Samantha Carlisle at 9:05 am, Nov 16, 2021 321-588 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.11.16 08:37:46 -09'00' Monty M Myers 10-407 DSR-11/16/21MGR29NOV21 BOPE test to 3500 psi. 24 hour notice to AOGCC for window milling. Variance to 20 AAC 25.112(i) Approved for alternate plug placement. DLB 11/16/2021 X dts 11/30/2021 11/30/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.30 11:29:01 -09'00' RBDMS HEW 12/1/2021 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: November 15, 2021 Re: PBU P1-06 Sundry Request Sundry approval is requested to set a whipstock and mill the window in the P1-06 pre-rig as part of the drilling and completion of the proposed P1-06A CTD lateral. Proposed plan for P1-06A Producer: Prior to drilling activities, screening will be conducted to drift for whipstock, MIT, and Caliper log. E-line will set a 4-1/2" whipstock. Service Coil will mill a 3.80” window + 10’ of formation out of the 4-1/2” casing (if scheduling needs arise, the rig will mill the window). See P1-06A PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. The well will kick off drilling and land in the Kuparuk. The lateral will continue in the Kuparuk to TD. The proposed sidetrack will be completed with a 3-1/4"x2- 7/8” 13Cr solid liner, cemented in place and selectively perforated post rig. This completion will completely isolate and abandon the parent Kuparuk perfs. This Sundry covers plugging the existing Kuparuk perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work - (Estimated to start in February 2022): 1. Slickline: Dummy WS drift and Caliper a. Drift and Caliper past whipstock setting location 2. Fullbore: MIT-T and CMIT-TxIA to 3,200 psi 3. E-line: Set 4-1/2” whipstock a. Top of whipstock set at 11,800’ MD (top of window – pinch point) b. Oriented 0° ROHS 4. Service Coil: Mill Window a. Mill Window I. MIRU Service Coil Window Milling Surface Kit II. Give AOGCC 24hr notice prior to BOPE test III. Test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 3,020 psi IV. Mill 3.80” window plus 10’ of rat hole V. Single string window exit out of 4-1/2” liner 5. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: x Reference PBU P1-06A PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 3,020psi a. Give AOGCC 24hr notice prior to BOPE test 2. Mill Window (only if not done pre-rig) 3. Drill Build and Lateral 4. Run and Cement Liner* 5. Freeze Protect and RDMO 6. Set LTP* (if needed) and perforate post rig * Approved alternate plug placement per 20 AAC 25.112(i) Possible underbalanced to pore pressure. PCE will be utilized to deploy/undeploy milling BHA. PTD to follow Possible underbalanced to pore pressure. PCE will be utilized to deploy/undeploy milling BHA. Sundry 321-588 The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: x A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. x The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil’s departure. x Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. Hole Size: x The window and 10’ of formation will be milled/drilled with a 3.80” OD mill. Well Control: x BOP diagram is attached. x AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. x Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. x BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. x BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. x 10 AAC 25.036 c.4.C requires that a BOPE assembly must include “a firewall to shield accumulators and primary controls”. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: x PBU P1-pad is an H2S pad. o The highest recorded H2S well on the pad was from P1-20 (850 ppm) in 2011. o Last recorded H2S on P1-06 was 83 ppm in 2021 Reservoir Pressure: x The maximum reservoir pressure is expected to be 3,900 psi at 8,800’ TVD (8.53 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 3,020 psi. x Reservoir pressure will be controlled with a closed circulating system and choke for backpressure to maintain overbalance to the formation. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 Coiled Tubing BOPs Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/20/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU P1-06 (PTD 196-137) Production Profile 10/07/2021 Report 10/12/2021 Please include current contact information if different from above. 37' (6HW Received By: 10/20/2021 By Abby Bell at 2:36 pm, Oct 20, 2021 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 ~:,, ~,i ~„ ~ ~~, (s~tr~~' ~1f-~~~~ I~ C`s L V r Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA P1 Dear Mr. Maunder, 3 ~qb ;, plP Q Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA P1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al P1-01 1900270 50029220180000 NA 0.2 NA 1.70 7/6/2009 P1-02A 2020650 50029217790100 NA 0.1 NA 0.90 7/8/2009 P1-03 1890130. 50029219120000 Cemented to flutes NA 0 NA 0.00 P1-04 1930630 50029223660000 NA 0.2 NA 1.70 7/8/2009 P1-OS 1930870 50029223780000 NA 0.2 NA 1.70 7/18/2009 P1-06 1961370 50029226950000 Sealed conductor NA NA NA NA P1-07A 2040370 50029219960100 SC Leak NA NA NA NA P1-08A 2021990 50029223840100 NA 1.2 NA 6.50 7/8/2009 P1-09 1961540 50029227040000 NA 14.5 NA 141.10 7/9/2009 P1-11 1920860 50029222840000 NA 0.2 NA 1.70 7/7/2009 P1-12 1910130 50029221340000 NA 0.6 NA 6.80 717!2009 P1-13 1930740 50029223720000 NA 1.5 NA 10.20 7/6/2009 P1-14 1930160 50029223380000 NA 1.5 NA 10.20 7/6/2009 P1-16 1930340 50029223490000 NA 0.7 NA 6.80 7/6/2009 P1-17 1930510 50029223580000 NA 1.7 NA 11.90 7/7/2009 P1-18A 2020760 50029229530100 NA 1.8 NA 8.50 7/7/2009 P1-20 1920940 50029222880000 NA 0.6 NA 3.40 9/12/2009 P1-21 1930590 50029223630000 NA 0.6 NA 5.10 7/7/2009 P1-23 1961240 50029226900000 NA 1.6 NA 13.60 7/7/2009 P1-24 1961490 50029227030000 NA 10 NA 107.10 12/13!2009 P1-25 1890410 50029219370000 Sealed conductor NA NA NA NA P1-G1 1921130 50029222980000 NA 0.2 NA 1.70 7/6/2009 03/06/08 ~l~'li~~~~~s~~r~ N0.4621 ~~/}~, Com an State of Alaska Alaska Data & Consulting Services '''~' ~j ~~~~ ~ p Y~ 2525 Gambell Street, Suite 400 U Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Pt.Mac,Milne Pt,Orion,Lisburne _u ~_w u ~ .... ns~.. ..F:.,., rlain RI Cnlnr CD C-41A 12021141 MEM LDL _ 02/25/08 1 1 MPS-01A 11970714 SCMT 02/21/08- 1 1 P1-06 11975757 PROD PROFILE q- 03/02/08 1 1 Pi-05 11998992 PROD PROFILE g' 02/29/08 1 1 P1-06 11975757 SCMT (Qj ~• ~ 03/02/08 1 1 09-23A 12045070 USIT ~- C ~ 03/02/08 1 1 L5-34 12057596 PROD PROFILE ~ ~ 02/28/08 1 1 W-40 11970816 PRODUCTION LOG _j 03/04/08 1 1 15-04B 12005202 MCNL ~d - t ~ 12/28/07 1 1 C-356 12021139 MCNL ~ 01/26/08 1 1 X-20A 11661178 CH EDIT PDC GR (MEM CORRELATION) _t 10/26/07 ~'} 1 L-219 12017479 CH EDIT PDC GR (IBC) - [ /(p 01/02/08 1 PLEASE AGKNUWLEDGE RECEIPT BY SILiNI'VCa `ANU Ii 1t IrU Fit~INl9'UNt I:UF'Y tHl: r1 I V: BP Exploration (Alaska) Ina '~' Petrotechnical Data Center LR2-1 900 E. Benson Blvd. i Anchorage, Alaska 99508 ~+ ti ~~ - 'p~~~)f i Date Delivered: ~; t, r; Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: C -3 03/06/08 NO. 4621 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 6~+r,~,t~01iC~ k ~ ty ~g 6F fi, ~ry~~~ Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~S 01i tVI/^it~ C,~ ki ti Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Pt.Mac,Milne Pt,Orion,Lisburne \n/ell Inh 3k Inn ncerriniinn naTa RI Cnlnr Cn C-41A 12021141 MEM LDL _ 02/25/08 1 1 MPS-O1A 11970714 SCMT vim} _ C 02/21/08 1 1 Pi-06 11975757 PROD PROFILE ;~ 03/02/08 1 1 Pi-05 11998992 PROD PROFILE '6r 02/29/08 1 1 Pi-O6 11975757 SCMT (~ "~-'~ 03/02/08 1 1 09-23A 12045070 USIT ~ ~ C '~ 03/02108 1 1 L5-34 12057596 PROD PROFILE ~ ~ 02/28/08 1 1 W-40 11970816 PRODUCTION LOG -j 03/04/08 1 1 15-04B 12005202 MCNL '~() - * C 12/28/07 1 1 C-35B 12021139 MCNL ¢ 01!26/08 1 1 X-20A 11661178 CH EDIT PDC GR (MEM CORRELATION) _I 10/26/07 'al'b 1 L-219 12017479 CH EDIT PDC GR (IBC) - C /(p 01/02/08 1 PLEASE ACKNOWLEDGE RECEIPT BY_,SIGNI~JG'ANJp FiEILHLVINCi'ONE COPY EACH TO: BP Exploration (Alaska) Inc. ! Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ ~/~~~~ ~- -~ ~ ~ i~)~;. Date Delivered: ~ ~ ,,,~ ~~,;: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ Received by: • • -3 <t:" ; ~ r'\ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program 0 2. Operator Suspend 0 RepairWeliD Pull TubingD Operation Shutdown D Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate ŒI WaiverD Stimulate D Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 196-1370 OtherD Name: BP Exploration (Alaska), Inc. Development ŒJ Stratigraphic D 9. Well Name and Number: P1-o6 10. Field/Pool(s): pt Mcintyre Oil Field 1 pt Mcintyre Oil Pool ExploratoryD ServiceD 6. API Number 50-029-22695-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 44.00 8. Property Designation: ADL-o34624 11. Present Well Condition Summary: Total Depth measured 12183 feet true vertical 9147.6 feet Effective Depth measured 12097 feet true vertical 9081.5 feet Plugs (measured) Junk (measured) None 11992,11730 Casing Conductor LIner Surface Perforation depth: Length 80 6322 6004 Size 20" 133# H-40 4-1/2" 12.6# 13Cr80 7" 26# NT80S MD TVD 36 116 36.0 - 116.0 5861 - 12183 4824.2 - 9147.6 35 - 6039 35.0 - 4944.3 Burst 2220 8430 7240 Collapse 1320 7500 5410 Measured depth: 11730 -11759,11759 -11761,11761 -11790,11828 -11848,11868 -11887,11888 -11898 11914 -11924,11950 -11960,11986 -12008,12008 -12017,12017 -12028 True vertical depth: 8799.53 - 8821.93, 8821.93 - 8823.47, 8823.47 - 8845.85,8875.15 - 8890.55,8905.95 - 8920.56, 8921.33 - 8929.02 8941.32 - 8949.01, 8968.96 - 8976.62, 8996.52 - 9013.35, 9013.35 - 9020.24, 9020.24 - 9028.65 Tubing (size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 33 5859 RECEIVED Packers & SSSV (type & measured depth): 4-1/2" Baker ZXP Packer @ 5861 4-1/2" Cameo WRDP-2 SSV @ 1977 APR 1 4 2004 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Dailv Averaae Production or Iniection Data Gas-Mcf Water-Bbl Casing Pressure 30.7 1641 2000 27.5 1502 1950 15. Well Class after proposed work: ExploratorvD Alaska Oil & Gas Cons. Commission Anchorage 13 Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl 4016 3870 Tubing Pressure 1745 1776 Development !XI ServiceD Copies of Loas and Surveys run 16. Well Status after proposed work: Operational Shutdown D OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. ISUndry Number or NIA if C.O. Exempt: N/A Daily Report of Well Operations! 17. I hereby certify that the foreaoina is true and correct to the best of mv knowledae. Contact Printed Name Signature Garry Catron Garry Catron J1¡~. Title Production Technical Assistant Phone 564-4657 Date 4/13/04 ORIGINAL ... BfL APR 1. 4 10"~ Form 1 0-404 Revised 12/2003 !' r"'\ r'\ . " P1-06 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/11/04 WELL FLOWING ON ARRIVAL (DRIFT FOR ADD PERF) DRIFT TO TOP OF SSSV WI 3.84" GAUGE RING PULLED 4-1/2 WRDP-2 (SER# HDS-1008) DRIFTED WI 33/8" DUMMY GUN & SAMPLE BAILER TOOLS SD @ 11,317' SLM DRIFTED WI 27/8" DUMMY GUN & SAMPLE BAILER TOOLS SD @ 11,839' SLM. TARGET 11,848' (MIT BAILER) ( UNABLE TO GET CORRECTED DEPTH) *** GAVE WELL BACK TO DSO TO BRING ON LINE *** 03/16/04 PERFORATED 11828'-11848' WITH 2 7/8" 6SPF HSD HMX POWERJET GUN CORRELATED WITH CCL TO SWS PERFORATION RECORD LOG RUN 16-SEP-1996. NEEDLE AND WING VALVES FOUND OPEN UPON ARRIVAL AND CLOSED. WELL SHUT IN FLUIDS PUMPED BBLS No Fluids Pumped 0 TOT AL Page 1 Of: ~ ,-.." lREE= WELLH~D= ACTUA TOR = KB. B.BI = BF. B.EV = KOP= Max Angle = Datum !'vi) = DatumlVD= --_? CWV BAKERC 42.38 P 1-06 SAFETY NOlES: TBG H<\NGER FMCGEN 6 @ 30' !'vi) 1975' 54 @ 4404 11788' 8800' SS . - 1997 H 4-112" Cð.WCOBALOSVLN, ID =3.812" I I WITH WRŒ'-2 (HDS-1008) GAS LIFT Mð.I\ÐRB.S ST MD TVD DEV 1YÆ VLV LATCH PORT D<\lE L - 1 4890 4168 48 Cð.-KBG2-LS DMY BTMINT 0 - 2 5794 4779 48 Cð.-KBG2-LS SO BTM INT 20 07/28/02 I Minimum 10 = 3.813" @ 1997' I 4-1/2" CAMCO BALO WRSSSV g Z'-f 5860' H 7" X 4/12", BAKERLlN:RTOP ZXP A<R ..---1 5977 H 4-1/2" I-ESX NP, ID =3.813" I 7" CSG, 26#, NT-80s, ID = 6.276" H 6039' ~ ~ - ---I 11382' H 4-1/2" I-ESX NP, ID =3.813", ELMD I PERFORATION SUMMARY REF LOG: WA DIR./GR ON 08/26/96 ANGLEA TTOP PERF: 39 @ 11730' IIbte: Refer to A"oductbn œ for historical perf data SIZE SPF INTERV AL OpnlSqz D<\ TE 3-3/8" 6 11730 -11761 0 09/16/96 3-3/8" 6 11759 - 11790 0 09/16/96 3-3/8" 6 11868 - 11898 0 08130/02 3-3/8" 6 11914-11924 0 08130/02 3-3/8" 6 11950-11960 0 08130/02 3-3/8" 6 11986 -12028 0 09/16/96 -, 111730' H FISH-1"GLVNOSECONE I I FBW H 12097' 4-1/2' lBGICSG, 12.6#, 13CR, ID = 3.958" H 12183' -. ~ I 11992' - FISH'OBSlRLCTION - LIB SHOWED OBSTRUCllON&HADWETAL RECES IMBEDŒD. HARD BOTTOM. DATE REV BY COMlilENTS DOl TE RBI BY COMlilENTS 09/01/96 ORiGNAL COMR.E1l0N 08/30/02 CWS/KK AŒ'ERFS 01/16/01 SIS-isl CONVERlED TO CANVAS 02/20/01 SIS-MD FINAL 08/02101 RNffP CORRECllONS 07/28/02 JB/KAK GLV C/O PONT MCNTYRE UNT WELL: P1-O6 PERMTIIb: 1961370 API lib: 50-029-22695-00 Sec. 16, T12N, R14E, 710' FEL, 1453' FSL BP Exploration (Alaska) 01/22/04 Schlumberger NO. 3095 Alaska Data & Consulting Services Company: State of Alaska 3940 Arctic Blvd, Suite 300 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color ( Well Job # Log Description Date Blueline Prints CD D.S.06-02 \ -::r'-=t -(Y=I.S{ 10874399 PROD PROFILE 11/22/03 1 E-35A ;Ë) n'; -- \ c, 10715373 MEM PROD PROFILE 12/27/03 1 P1-06\ Q' l ()'- \ ~~ "::¡- 1 0703984 PPROFILE/DEFT/GHOST 12/24103 1 D.S. 15-49A I~f)()' t~' 10679043 LDL 12/23/03 1 M-38A .!2.)("') -. t ~~ 10709678 LDL 12/25/03 1 D.S.09-15 , -q-::::¡ -Ú"'.:s( () 10709680 STATIC SURVEY 12/27/03 1 X-27 qTr~C) ,d"1 10679046 LDL 01/08/04 1 , i . ( - \ .,,, ,".' ,,' ,'" ,,;1 ,,'. .,*'.1'", .'<:~: '?, .,':' '.< ~~ )"i,"}~""';¡I": .,'~' ',' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc," Schlumberger GeoQuest Petrotechnical Data Center LR2-1 RECE V 3940 Arctic Blvd, Suite 300 900 E. Benson Blvd. . I 'ED Anchorage, AK 99503-5711 Anchorage, Alaska 99508' ATTN: Beth I ^~"I -.: C: "004 '''----- ,,""N,........ . 0i,r~ \) ,I L -'--'~ ' \"" Date Delivered: Received by: "'N'\ '-~ 1\/'-.. \ '--Ii. Q.C~~C~.,V-- AJa,kaOiI & Gas Cons. Commlian An. C::(t"I'Àr~1.1,'¡"'\I¡,è It::,, t',","",' \(,'''\r~!L";) t;ù (ù) ">nni¡ (~~Plï\)ll'tl¡I~btl.:' r J.:.aJ 'J¡ 0) LlH3SJ' :-"""'",<'~:--:,--,"':"',:-, .:'\ \ \.. Schlumberger Alaska Data & Consulting Services 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 11/11/03 NO. 3028 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD P1-02A Y-~C~ - *'~-~' G-12B ~ ~{'(<'~ · 10672311 RST-SIGMA 09/14/03 - ~ 10563472 MCNL 09/29103 D.S. 5-02~~ ~ L ~ 10558550 MCNL 06110/03 D.S. S4SB ~N-~ -3 ~ ~0SSSSSS MCNL 0S/~S/03 E-14A, ~-, ~.~ 10560299 RST-SlGMA 09/12'03 1 P~-Os 1~-k-6~ ~os743saaST-S~aA ~0/04/03 P~-OS lq ~-I~ ~oss03~2RST-SlGMA 1011S/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Ala,.~.ka 99508 Date Delivered: R _CEIVED NOV 2 4 200 Gas Oons. O0mmieeion Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received by: '~t~..~ ~~ '~'"~.¢~_¢::%.~O.~/-¢- MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Julie Heusser, ~' ,~\~'~ DATE: Commissioner Tom Maunder, ~~~SUB~CT~ \ P. I. SuperVisor ~,[~'5' John H Spaulding, Petroleum Inspector April 10, 2001 SVS Tests BPX PBU LGI & PM-O1 April 11, 2001: I traveled to BPX's Lisbume Gas Injection (LGI) and also on to the Point Mclntyre PM-01 location to witness Safety Valve Testing. The AOGCC SVS test reports are attached for reference. As noted 3 failures were obserVed on both pads; with 2 being repaired and retested immediately. The third failure a sssv and will need further attention. Mark Wysocki, lead operator was training 2 new hires. The crew did an excellent job. Summary: I witnessed the SVS tests on LGI and PM-01 LGI, 3 wells, 9 components, 1 failure, 11% failure rate PM-01, 11 wells, 33 components, 2 failures, 6% failure rate Attachment; Svs bpx igi 4-10-0 ljs Svs bpx pm-01 4-10-01js Nqn Confidential Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Mar..k,, Wysoeki AOGCC Rep: John H- Spaulding Submitted By: John Spaulding_ Date: Field/Unit/Pad: .I~.,Mc. In..tyre/PBU/PM-01 Separator psi: LPS 460 HPS 4/9/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Sum.,ber umber ,.p,.sI ..... psi Trip ,.C?deC. ode,.Code Passed aASo .CYCL 12 1~J10370 Pi-o2 1880050.................. P1-03 l~b(Jl3'0 460 550 310 P P P OIL Pi,04"' 195063'0 460 .... 700 700' "i~ ..... P" p OIL P1-05 ']930870 460 "350 " 300 ' P P ~ ..... OiL ~ 1961370 4~0~ '...170° " ..'67~ ' P 'P", ..P, ........ OIL P1-07 1891340 P1-08 1930980 ..... 460 1500 ...... 1200 ' "P P ' P ..... OIL Pl-09 1'~'6i540 460 350 300: "P P p '~ 6Ii~ pl-lt' 1~20860' 460" ' 350 250" 'P' ' P P ..... OIL Pl-12 19101'~6 ......... :Pl-13 19307~0 460 1500 "'1150; P ' 'P'" P .......... oIL 131-17 .... 1930510" ' 460 3'~0 "580 P "~ P OIL P1-20 19209401 460 350 175! 3 P P 4/9/01 OIL i/1.23' ' 196i240 ................. P1-24 1961490 P1-GI' i'9211301 3600! 2906 '5856 P .... " P' P ...... GINj Wells: 11 Components: 22 Failures: 2 Failure Rate: g.og% I-19o my Remarks: P1-08 & P1-3 were cho,ked. ,!~.,ek,.. hence t.he .tfigher. pilot settings P'I'-20' Pilot reset ~md retested RJF 1/16/01 Page 1 ofl 010409-SVS PM-01 PBU-js Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: M,ark Wysocki AOGCC Rep: John H. Spaulding Submitted By: John Spauld'mg FieldfLlnit/Pad: -Lisburne/PBU/LGI Separator psi: LPS Date: 4/9/01 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE LGI-02 1861400 3800 2900 2300 ~ P P 4/9/01 GINJ LGI-04 1880130 LGI-06 1860670 3800 2900 2500 P P P GINJ L Vo8 86o5 o........... LOI-10 18~0690 3800 2600 2300 P P P " OlNJ ! LGI- 12 1860540 , , , Wells: 3 Components: 6 Failures: 1 Failure Rate: 16.67oA~19o Day ~ Remarks: ~LGI-02 PRot tripped to lo.,,w, ~ ,was r~e.set.-ret .e~text' an~.,,passe~.. ......... RJF 1/16/01 Page tofl 010409-SVS LGI Lisbume-js PERMIT 96-137 96-137 96-137 96-137 96-137 96-137 96-137 96-137 AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS RES / GR- MD RES / GR- TVD 7477 ~/~12040-12188 ~045-9153 ~ES/GR STAT PRESS SRVY L 11656-11915 PERF L 11275-12004 MWD SRVY ~/SPERRY 0-12183. / PSL SRVY ~B 0-12050. PROD-SPIN/TEM/ ~/PRES 11600-12020 Page: 1 Date: 08/12/98 RUN RECVD FINAL 10/10/96 FINAL 10/10/96 8 10/10/96 FINAL 10/11/96 FINAL 10/11/96 06/30/97 06/30/97 FINAL 11/05/97 10-407 ~R~COMPLETION DATE ~//7/~ / DAILY WELL OPS /~/f0 /qL / TO q/l) /~ / Are dry ditch samples required? yes ~3And received? Was the well cored? yes ~z~Analysis & description received? Are well tests required? ~/~es ~ Received? ycs no ~ Well is in compliance Initial COMMENTS STATF OF ALASKA OIL AND ~A$ CONSERYATIO~ COMMI8810N 1. Status of Well Classification of [] Oil [] Gas J--1 Suspended 1--1Abandoned [] Service ...... 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-137 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22695 ~' ~:~::'-'z:-;::.'--T'*, Point Mclntyre 1453' NSL, 710' WEL, SEC. 16, T12N, R14E, UM i '- :" "_~0i., ~ At top of productive interval i MTF_ ~ ~' :10. Well Number NS', "w', "14", UM 2315' NSL, 1149' EWL, SEC. 14, T12N, R14E, UM Point Mclntyre 5. Elevation in feet (indicate KB, DF, etc.) 1 6. Lea~'C(~'~)~l~JJb~ and Serial No. KBE = 44'I ADL 034624 12. Date Spudded8/11/96 J 13' Date T'D' Reached ! 14' Date C°mp" Susp" °r Aband'115' Water depth' if °ffsh°r° 116' N°' °f C°mploti°ns8/27/96 9/17~96 N/A MSLI One 17. Total Depth (MD+TVD)12183 9149 FT1118' 'lu' Back Depth (MB+TVa)II9' Directi°nal Survey 120' Depth where SSSV soil21' Thickness Of PermafrOst12097 9083 I:-rI []Ye, [~]No 1974' MD 1800' {Approx.) 22. Typo Electric or Other logs Run Gyro, MWD, GI:I/DII_/BHC, GR/AC/DIFL/, LWD, RES/GR 23. CASING~ LINER AND CEMENTING RECORD CASING SE-FFING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 133# H-40 Surface 110' 30" 260 sx Arcticset (Approx.) 7" 26# NTSOS 35' 6039' 8-1/2" :866 sx Cold Set III, 177 sx 'G', 250 sx Cold Set II 4~1/2" 12.6# 13CR 5861' 12183' 6" 355 sx Class 'G' 2~'i' Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13CR 5861' 5861' MD TVD MD TVD 11730'-11761' 8800'-8824' 11759'-11790' 8822'-8846' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 11986'-12028' 8997'-9030' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 75 bbls diesel 27. PRODUCTION TEST 0 i'~ i ~ i ;'f'\l Date First Production I Method of Operation (Flowing, gas lift, etc.) // \ September 21, 1996I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MOF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL O~L GRAVITY-APl (CORR) Press. 24-HOUR RATE .... 28. 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 UB1 11712' 8786' Zone UA4 11746' 8812' Zone UA1 11782' 8840' Zone LB1 11979' 8992' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the eejoing is nd rect to the best of my knowledge SteveShu~tz .. Title Senior Drilling Engineer . . Date P1-06 Prepared By Name/Number: Well Number Permit No. / Approval No. INSTRUCTIONS Q£NERAL.' 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 ~,ND 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 Date/Time 10 Aug 96 11 Aug 96 12 Aug 96 13 Aug 96 14 Aug 96 15 Aug 96 16 Aug 96 Pt Mac 1 Progress Report Well P1-06 Rig Doyon 14 Page Date Duration Activity 22:00-02:00 02:00-04:30 04:30-06:00 06:00-07:30 07:30-09:00 09:00-09:30 09:30-11:30 11:30-12:30 12:30-13:30 13:30-15:30 15:30-18:30 18:30-06:00 06:00-14:30 14:30-15:15 15:15-16:00 16:00-06:00 06:00-07:30 07:30-10:00 10:00-11:00 11:00-21:30 21:30-22:00 22:00-00:30 00:30-01:30 01:30-02:00 02:00-02:30 02:30-03:00 03:00-03:30 03:30-06:00 06:00-15:30 15:30-16:00 16:00-18:30 18:30-21:00 21:00-23:00 23:00-03:45 03:45-04:30 04:30-06:00 06:00-06:15 4hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 2hr lhr lhr 2hr 3hr 11-1/2 hr 8-1/2 hr 3/4 hr 3/4 hr 14hr 1-1/2 hr 2-1/2 hr lhr 10-1/2 hr 1/2 hr 2-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 9-1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr 2hr 4-3/4 hr 3/4 hr 1-1/2 hr 1/4 hr Rig moved 100.00 % Rigged up Divertor Rigged up Kelly Rigged up Kelly (cont...) Made up BHA no. 1 Held safety meeting Circulated at 43.0 ft Drilled to 140.0 ft Made up BHA no. 1 Drilled to 322.0 ft Set tool face Drilled to 1191.0 ft Drilled to 2146.0 ft (cont...) Pulled out of hole to 1200.0 ft R.I.H. to 2146.0 ft Drilled to 4012.0 ft Drilled to 4199.0 ft (cont...) Pulled out of hole to 2100.0 ft R.I.H. to 4199.0 ft Drilled to 5317.0 ft Circulated at 5317.0 ft Pulled out of hole to 5317.0 ft Pulled BHA R.I.H. to 1542.0 ft Tested MWD - Via string Pulled out of hole to 1085.0 ft Pulled BHA R.I.H. to 5317.0 ft Drilled to 6050.0 ft Circulated at 6050.0 ft Pulled out of hole to 1100.0 ft R.I.H. to 6050.0 ft Circulated at 6050.0 ft Laid down 5000.0 ft of 5in OD drill pipe Pulled BHA Rigged up Casing handling equipment Held safety meeting 06:15-12:00 12:00-13:30 13:30-13:45 13:45-14:00 14:00-14:30 14:30-15:00 15:00-18:00 18:00-20:00 20:00-22:00 22:00-23:30 23:30-03:30 03:30-03:45 03:45-06:00 06:00-07:30 07:30-08:00 08:00-09:30 09:30-10:00 5-3/4 hr 1-1/2 hr 1/4 hr 1/4hr 1/2hr 1/2 hr 3hr 2hr 2hr 1-1/2 hr 4hr 1/4 hr 2-1/4 hr 1-1/2 hr 1/2hr 1-1/2 hr 1/2 hr Ran Casing to 6038.0 ft (7in OD) Circulated at 6038.0 ft Held safety meeting Pumped 70.000 bbl spacers - volume (null) Mixed and pumped slurry - 336.000 bbl Displaced slurry - 228.000 bbl Rigged down Casing handling equipment Wait on cement Rigged down Divertor Mixed and pumped slurry - 43.000 bbl Rigged up All functions Held safety meeting Tested All functions Tested All functions Installed Bore protector Serviced Kelly/top drive hose Tested Kelly/top drive hose 1 18 June 97 Facility Date/Time 17 Aug 96 18 Aug 96 19 Aug 96 20 Aug 96 21 Aug 96 22 Aug 96 Pt Mac 1 Progress Report Well P1-06 Rig Doyon 14 Page Date Duration Activity 10:00-11:30 11:30-15:00 15:00-15:30 15:30-16:00 16:00-16:30 16:30-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-06:00 06:00-08:00 08:00-08:30 08:30-09:30 09:30-10:00 10:00-18:30 18:30-19:30 19:30-21:30 21:30-22:00 22:00-22:30 22:30-00:30 00:30-01:30 01:30-03:30 03:30-06:00 06:00-08:00 08:00-08:30 08:30-09:00 09:00-09:30 09:30-20:30 20:30-21:30 lhr 1/2 hr 8-1/2 hr lhr 2hr 1/2hr 1/2 hr 2hr lhr 2hr 2-1/2 hr 2hr 1/2 hr 1/2 hr 1/2 hr llhr lhr Made up BHA no. 3 Pumped out of hole to 5861.0 ft Washed to 5955.0 ft Tested Casing - Via annulus and string Held drill (Kick (well kill)) Drilled cement to 6038.0 ft Drilled to 6070.0 ft Circulated at 6070.0 ft Performed formation integrity test Drilled to 6908.0 ft Drilled to 7074.0 ft (cont...) Circulated at 7074.0 ft Pulled out of hole to 6030.0 ft R.I.H. to 7074.0 ft Drilled to 7590.0 ft Circulated at 7590.0 ft Pulled out of hole to 440.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 6030.0 ft Serviced Block line R.I.H. to 7590.0 ft Drilled to 7734.0 ft Drilled to 7765.0 ft (cont...) Pumped out of hole to 7195.0 ft Laid down 31.0 ft of 3-1/2in OD drill pipe R.I.H. to 7765.0 ft Drilled to 8476.0 ft Serviced Block line 21:30-06:00 06:00-15:30 15:30-16:00 16:00-17:30 17:30-18:00 18:00-06:00 06:00-14:00 14:00-14:15 14:15-14:30 14:30-15:30 15:30-16:00 16:00-06:00 06:00-13:30 13:30-14:30 14:30-18:30 18:30-19:00 19:00-19:15 19:15-19:30 19:30-20:30 20:30-22:30 22:30-23:30 23:30-03:30 03:30-04:00 04:00-06:00 06:00-16:30 8-1/2 hr 9-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 12hr 8hr 1/4 hr 1/4 hr lhr 1/2hr 14hr 7-1/2 hr lhr 4hr 1/2 hr 1/4 hr 1/4 hr lhr 2hr lhr 4hr 1/2hr 2hr 10-1/2 hr Drilled to 8937.0 ft Drilled to 9527.0 ft (cont...) Circulated at 9527.0 ft Pulled out of hole to 7590.0 ft R.I.H. to 9527.0 ft Drilled to 10384.0 ft Drilled to 10798.0 ft (cont...) Held safety meeting Circulated at 10798.0 ft Drilled to 10861.0 ft Serviced Shaker discharge line Drilled to 11528.0 ft Drilled to 11800.0 ft (cont...) Circulated at 11800.0 ft Pulled out of hole to 443.0 ft Pulled BHA Removed Bore protector Installed Bore protector Made up BHA no. 5 R.I.H. to 7070.0 ft R.I.H. to 7918.0 ft Jarred stuck pipe at 7918.0 ft Circulated at 7918.0 ft Jarred stuck pipe at 7918.0 ft Jarred stuck pipe at 7918.0 ft (cont...) 2 18 June 97 Facility Date/Time 23 Aug 96 24 Aug 96 25 Aug 96 26 Aug 96 27 Aug 96 Pt Mac 1 Progress Report Well P1-06 Page 3 Rig Doyon 14 Date 18 June 97 16:30-22:00 22:00-22:15 22:15-01:30 01:30-06:00 06:00-08:00 08:00-09:00 09:00-10:00 10:00-10:15 10:15-17:30 17:30-18:00 18:00-19:00 19:00-22:00 22:00-00:00 00:00-00:15 00:15-00:30 00:30-04:30 04:30-04:45 04:45-05:00 05:00-06:00 06:00-08:00 08:00-08:30 08:30-10:00 10:00-11:30 11:30-13:00 13:00-14:00 14:00-14:30 14:30-15:00 15:00-17:30 17:30-22:30 22:30-06:00 06:00-07:30 07:30-08:30 08:30-11:00 11:00-14:00 14:00-15:30 15:30-19:30 19:30-20:00 20:00-20:15 20:15-23:30 23:30-00:00 00:00-00:30 00:30-00:45 00:45-06:00 06:00-06:15 06:15-09:30 09:30-11:30 11:30-16:30 16:30-17:30 17:30-20:30 20:30-20:45 20:45-22:30 22:30-03:30 03:30-06:00 06:00-09:00 Duration 5-1/2 hr 1/4 hr 3-1/4 hr 4-1/2 hr 2hr lhr lhr 1/4 hr 7-1/4 hr 1/2 hr lhr 3hr 2hr 1/4 hr 1/4 hr 4hr 1/4 hr 1/4 hr lhr 2hr 1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr lhr 1/2 hr 1/2 hr 2-1/2 hr 5hr 7-1/2 hr 1-1/2 hr lhr 2-1/2 hr 3hr 1-1/2 hr 4hr 1/2 hr 1/4 hr 3-1/4 hr 1/2 hr 1/2 hr 1/4 hr 5-1/4 hr 1/4 hr 3-1/4 hr 2hr 5hr lhr 3hr 1/4 hr 1-3/4 hr 5hr 2-1/2 hr 3hr Activity Conducted electric cable operations Held safety meeting Conducted electric cable operations Laid down 5800.0 ft of 3-1/2in OD drill pipe Laid down 6600.0 ft of 3-1/2in OD drill pipe (cont...) Made up BHA no. 6 Serviced Block line Held safety meeting Singled in drill pipe to 7810.0 ft Fished at 7810.0 ft Circulated at 7918.0 ft Pulled out of hole to 490.0 ft Pulled BHA Retrieved B ore protector Installed BOP test plug assembly Tested BOP stack Retrieved BOP test plug assembly Installed B ore protector Made up BHA no. 6 R.I.H. to 5939.0 ft Circulated at 5939.0 ft R.I.H. to 7792.0 ft Reamed to 7962.0 ft R.I.H. to 9869.0 ft Circulated at 9869.0 ft R.I.H. to 10346.0 ft Circulated at 10346.0 ft R.I.H. to 11434.0 ft Reamed to 11800.0 ft Drilled to 12000.0 ft Drilled to 12050.0 ft (cont...) Circulated at 12050.0 ft Pulled out of hole to 6030.0 ft R.I.H. to 12050.0 ft Circulated at 12050.0 ft Pulled out of hole to 440.0 ft Pulled BHA Held safety meeting Conduct braided cable operations - 5/16 size cable R.I.H. to 440.0 ft Pulled BHA Held safety meeting Conducted electric cable operations Held safety meeting Conducted electric cable operations Rigged up sub-surface equipment - Other sub-surface equipment Conducted electric cable operations Rigged down sub-surface equipment - Other sub-surface equipment Pulled out of hole to 90.0 ft Held safety meeting Pulled BHA Made up BHA no. 7 R.I.H. to 6000.0 ft R.I.H. to 12017.0 ft (cont...) Facility Date/Time 28 Aug 96 29 Aug 96 30 Aug 96 31 Aug 96 01 Sep 96 Pt Mac 1 Progress Report Well P1-06 Page 4 Rig Doyon 14 Date 18 June 97 09:00-09:30 09:30-09:45 09:45-10:30 10:30-17:00 17:00-18:30 18:30-19:30 19:30-20:30 20:30-22:30 22:30-04:00 04:00-05:00 05:00-06:00 06:00-17:00 17:00-17:30 17:30-18:00 18:00-23:30 23:30-06:00 06:00-10:00 10:00-11:30 11:30-12:00 12:00-13:30 13:30-14:00 14:00-14:30 14:30-18:00 18:00-19:00 19:00-19:30 19:30-02:00 02:00-04:00 06:00-08:00 08:00-10:00 10:00-10:30 10:30-11:00 11:00-12:00 12:00-15:30 15:30-19:00 19:00-21:00 06:00-08:00 08:00-08:30 08:30-11:30 11:30-12:30 12:30-19:00 19:00-19:30 19:30-20:00 20:00-00:00 00:00-01:00 01:00-04:00 Duration 1/2 hr 1/4 hr 3/4 hr 6-1/2 hr 1-1/2 hr lhr lhr 2hr 5-1/2 hr lhr lhr llhr 1/2hr 1/2hr 5-1/2 hr 6-1/2 hr 4hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr lhr 1/2 hr 6-1/2 hr 2hr 2hr 2hr 1/2 hr 1/2 hr lhr 3-1/2 hr 3-1/2 hr 2hr 2hr 1/2 hr 3hr lhr 6-1/2 hr 1/2 hr 1/2 hr 4hr lhr 3hr Activity Washed to 12050.0 ft Drilled to 12055.0 ft Circulated at 12055.0 ft Drilled to 12183.0 ft Circulated at 12183.0 ft Pulled out of hole to 10.0 ft Logged hole with LWD: Formation evaluation (FE) from 11950.0 ft to 12085.0 ft Circulated at 12183.0 ft Pulled out of hole to 380.0 ft Pulled BHA Rigged up Casing handling equipment Ran Casing to 6038.0 ft (4-1/2in OD) Circulated at 6038.0 ft Rigged up High pressure lines Ran Casing on landing string to 12183.0 ft Circulated at 12183.0 ft Circulated at 12183.0 ft Mixed and pumped slurry - 137.000 bbl Set Production packer at 5860.0 ft with 4500.0 psi Circulated at 5860.0 ft Rigged down High pressure lines Tested Tie back packer - Via annulus and string Pulled Drillpipe in stands to -0.0 ft Laid down 30.0 ft of Drillpipe Retrieved Wear bushing Ran Tubing to 2200.0 ft (4-1/2in OD) Tested SCSSSV control line Ran Tubing to 5860.0 ft (4-1/2in OD) Space out tubulars Circulated at 5860.0 ft Stung into Tie back packer Tested Tubing - Via annulus and string Rig waited: Equipment Conduct braided cable operations - 5/16 size cable Rig waited: Equipment Set downhole equipment (wireline) Tested Production equipment Conducted slickline operations on Slickline equipment - Retrival run Tested Tubing - Via string Conducted slickline operations on Slickline equipment - Setting run Rigged down sub-surface equipment - Control lines Rigged up Accessories Rigged up BOP stack Rigged up Additional services Rigged down Well control , EL Well Work Log Date Description DS-Well 9/1 6/96 ~ P1-06 FTP/FrP PS! - ' lA I~SI OAP--~ - ISITP IMln ID' ~SSV nipple NA NA ' 500 .ps:i 3.812'O2104 CAMCOBAL-O $--SSV Information' Tub~I~,~ ~r Ca~ing Problems OUT ' 4 l/2'- ctE#a' ::.swS · .. ~ctE~20[~' om #3 - C,/E #4 C/E #S .... $24,332 '! 3("~ ' ' ~i~al (Rm~ov,)~ Die, el (non Recov) AFE #..' ' CC~ v' Iclm~ Activity ' 200097'",/' - PMDS009DH: I '71 ~-P I~,~ I~-[~' -r.go-: ':" ,. '"-Log E.~ - . . ' - -- 07:30 SW$ ON LOCATION ... 8293 !G. JOHN ,S~N) ..... . ........ 09:15 ': RIH WITH 1 .-20' 3 3/8,- HSD-'PERF GUN AND GAMMA .F~..Y TOOL 11:25 TIE INTO DIL DATED 8/28/96, FOUND TD AT 12029"-" 11:50. iPERFORATE 12016, - 120~', 6 SPF - " - . ......... i i i 7- l. _ - ...... 12:00 -. 13:00 i AT SURFACE .- ALL SHOTS FIRED ' '- : i , ~ I. i , Il [ I · 14:00 RIH WITH 30' 3 318"HSD PERF GUN ' -15:10 ITIE Ihq'O X NII~LE ^T 11~ . . _ . 15:25 ! pERFORATE l1986 TO 12017 ! 15:3o ~ ' '16:30 ATSURFAC. E.- ALLSHOTS FIEED ' .' -" _ ._ ' 17:00 RIM WITH 30' 3 3/8" HSD PERF GUN '" -:18:35 TIE INTO X NIPPLE AT11~ ' ' -.. ... 1!8:40 -- - . 20:00 AT SURFACE - ALL SHOTS FIRED · :20:10 F~O DOWN -- : 21:00: 'LEAVE LOCATION " . . ' · ! · · . . . · . : . ' .- ,,= ·. , ! i i illl JU I__1 i ! i _ , i : i , , :7 i i . : i~. i _ __ i ..... __ i. . -- · ': :'..::"'.' '. -:.'."~ ..:.:.::.~ ~Pm-Jotatin'gl4nterval.,'(BH depths) &. Gun.'l_nfo.."(Insert :more Iinea .aa ~neeee~ary) i ~. .. -- , - , Top (fi)_ Bottom E;PF Grams/EHD/TTP Phasing Orient OIBIU Zone ,. A..d/.R~.p.~rf. 11986 12028 6 20.5/.4/21.9 80 RDM B LB1 INIT ,. .... · .11759 11790 6 20.51.4121 :g 60 ~ B UAl,UA4 INIT · :'.:.~p:~ .o~r;~.PR__OF:~,Well:..rate.'(attach'~':W~30) .. _ _ __ ,~-IP8 ' ~'P. umP ,in.' 'J~ge' (EDL~. PNL~ ere,) BO~. F/lIP= · Tot. G~e: ~i:1~' BW~.! wc (%): Pre~,: eh O~s: Chok,~.°' , ,. Tem ...... , ___ Signed Page No. of SFNT BY'I~SSAGE CF__NTF~ ; 6-20-97 ; lb'Ob ; .~bu rnv~,--, o,.,, o~,.,o~.,.,.,,,-,-~., ,., EL Well Work Log ~a~e" DescriptiOn ....... DS-Well 9 / 1 7/9 6 PERF/STATIC P 1-06 FTP~'P PSI ' '/~ PSI O~,'PSI ISITP lMin ID SSSV nipple NA NA 550 psi CAMCO BAL-O SSSV Information: TUbuM~ ·or'Casing Problems PBTD -- - OUT 4 1/2' 12029' C/E#1 SWS v'. '! CIE#2 CiE- #3 * O/E-~4' . C/I~' its S13,444 = Diesel (Recov.) ' " Diesel (non Recov) AFE # GGe " IClaa~ iActlvity ....... 2C0097 Time 'L°g~ Eh:try " _ ..... 07:30 SWS ON LOCA,=-nON 8293 {G. JOHNSON)- ' . ......... · 08:30 RIH WITH I 30' 3 3/8"" HSD PERF GUN . i · .. , . m. ; ... · · · _ _ · 10:00 TIE INTO X NIPP.LE LOCATED AT 11382' (GR/CCL. T. IE' IN MADE 9116/967 10:~1.5. ,. PERFORATE 11730 - 1.1.76!, 6 SP.F.., ' .... 10:20 11:30 AT SURFACE- ALL SHOTS FIRED ' - ' ....... - ,Ill ._ ..... · ... I . 12:30 RIH WITH 6' .WT. BAR,GR,CCL, PRE,~:~,TEMP ' 13:50 'liE iI~ro GR-FROM DIL DATED 8/~8/~ 14'.05 TAKE PRESSURE STOP AT' 11915' f8g00' SS}, PRESS DROPPING_ ..Of=F . 14:35 iTAKE PRE~SURE STOP AT 11786' {8800' SS), PRESS DROPPING OFF 1. 4 ;50 ',TAKE PRESSURE STOP AT 1165~_ f8700' SS), pRESS DROPPING...OFF ..... 15:05 i~ . . '-~ 6:'3~3 ATmRFACE' BE~O RIG DOWN ...... ' ' ' ' 17:30 ' LEAVE LOCATION ' . i ~ --i , , ..... · . .. · , , . · . i i i i i . , . . · · . . I iii . ii · i i · 1 : i, .j. ; ..... . _ _ __ · , .. ,1...1 11 , - -- i i : . i i i · ~e~'"l~=:Sum. maqt..-:.:~ddr, s~...,ach.'obl~tive Ii~ted in Job ~uest e, g, 'spIit,~ ~OC pick, chann®l,, el~, I . · ...'"" i _ . -- . · : · . .i · '. .... "Perfomtin'9:ln,te .wal (l~l:lC..S deptl~a} & Gun Info. (insert.more lines,es nece.sary} Top .(f'ti Bottom ~ Gr~m~.EHD/TTP Ph~in9 Orient ~ OIB/U Zone AdlReper~ : . 1 1730 1 17,6,.1, 6 20.S/.4/21.9 e0 FDM B UAI,OA4 ~1~ '"~P:':or'~lPl~13R:"~'.W._,~l.~,rate:(ettaoh ,:W530)' .SBHPS . "Pump in'Logs (LnL, PNL, ,em.) : BOPD: F/ITP: MD: .. Tot. Gas: GOR: SS: - BWPD: WC (%): Press: GL Gas: Choke °' Temp: i i ! II I Signed :Page No. of O C/351,/'O5. 'I ..... P 1-06_Directional_Surv.XLS API500292269500 Survey Type: MEASURED WHILE DRILLING Company: SPERRY SUN Survey Date: Survey Top: 50' MD Survey Btm: 12,183' MD Kickoff Depth: Max. Dogleg: 6.4°/100' @ 4,310' MD Avg. Angle below KOP: Max. Angle: 53.8° @ 4,404' MD MD TVD SS INCLINE AZIMUTH DOGLEG ASP X ASP Y 0 0.00 -42.38 0.00 0.00 0.0 674,346.0 5,994,586.1 50 50.00 7.62 0.10 129.40 0.2 674,346.0 5,994,586.0 150 1 50.00 107.62 0.20 144.30 0.1 674,346.2 5,994,585.8 200 200.00 157.62 0.20 95.90 0.3 674,346.4 5,994,585.8 250 250.00 207.62 0.30 55.30 0.4 674,346.6 5,994,585.8 300 300.00 257.62 0.40 72.10 0.3 674,346.8 5,994,586.0 350 350.00 307.62 0.60 77.80 0.4 674, 347.2 5,994,586.1 400 400.00 357.62 0.60 33.20 0.9 674,347.6 5,994,586.4 450 450.00 407.62 1.00 11.50 1.0 674,347.8 5,994,587.0 500 499.99 457.61 1.50 20.50 1.1 674,348.1 5,994,588.1 550 549.96 507.58 2.60 27.90 2.3 674,348.9 5,994,589.7 600 599.89 557.51 3.50 34.80 1.9 674,350.2 5,994,592.0 650 649.74 607.36 5.20 28.20 3.5 674,352.1 5,994,595.3 700 699.46 657.08 7.00 18.50 4.1 674,354.0 5,994,600.2 750 749.12 706.74 6.30 12.50 2.0 674,355.4 5,994,605.8 793 791.88 749.50 5.90 12.20 0.9 674,356.3 5,994,610.3 873 871.39 829.01 5.65 14.70 0.4 674,358.0 5,994,618.2 962 960.03 917.65 4.74 15.50 1.0 674,359.9 5,994,626.0 1,051 1,048.94 1,006.56 ' 2.06 30.30 3.1 674,361.6 5,994,631.0 1,141 1,139.34 1,096.96 2.05 59.30 1.1 674,363.7 5,994,633.3 1,234 1,231.41 1,189.03 2.37 60.70 0.4 674,366.8 5,994,635.1 1,327 1,324.51 1,282.13 2.50 62.00 0.2 674,370.2 5,994,637.1 1,421 1,418.25 1,375.87 3.53 69.90 1.2 674,374.7 5,994,639.1 1,513 1,510.20 1,467.82 4.83 76.00 1.5 674,381.0 5,994,641.2 1,606 1,603.09 1,560.71 6.76 87.60 2.4 674,390.3 5,994,642.6 1,699 1,695.51 1,653.13 7.81 89.60 1.2 674,402.1 5,994,643.1 1,791 1,785.80 1,743.42 7.72 92.50 0.4 674,414.4 5,994,643.2 1,883 1,876.82 1,834.44 9.29 94.90 1.8 674,428.0 5,994,642.6 1,976 1,968.37 1,925.99 10.95 93.40 1.8 674,444.4 5,994,641.8 2,069 2,059.70 2,017.32 12.74 93.80 1.9 674,463.5 5,994,641.1 2,163 2,1 50.65 2,108.27 15.53 94.80 3.0 674,486.4 5,994,639.9 2,258 2,241.30 2,198.92 18.79 97.20 3.5 674,514.3 5,994,637.5 2,350 2,328.65 2,286.27 19.46 96.80 0.7 674,544.4 5,994,634.6 2,442 2,415.38 2,373.00 21.10 93.60 2.1 674,576.4 5,994,632.4 2,538 2,503.90 2,461.52 24.12 89.40 3.6 674,613.2 5,994,632.4 2,631 2,586.71 2,544.33 28.16 89.20 4.4 674,653.8 5,994,633.9 2,723 2,667.96- 2,625.58 28.91 90.00 0.9 674,698.0 5,994,635.2 2,816 2,748.80 2,706.42 31.02 89.80 2.3 674,744.6 5,994,636.4 2,910 2,827.31 2,784.93 34.06 89.70 3.3 674,794.7 5,994,637.7 3,003 2,902.73 2,860.35 38.08 91.10 4.40 674,849.6 5,994,638.6 3,095 2,973.79 2,931.41 40.37 92.60 2.7 674,907.6 5,994,638.1 Page 1 of 3 ORIglN/ E P 1 - 06_Directional_Su rv.XLS MD TVD SS INCLINE AZIMUTH DOGLEG ASP X ASP Y 3,190 3,043.82 3,001.44 44.83 93.50 4.73 3,283 3,107.91 3,065.53 48.53 92.60 4.0 3,376 3,168.87 3,126.49 49.29 93.50 1.1 3,471 3,231.61 3,189.23 48.11 90.40 2.8 3,563 3,293.67 3,251.29 47.32 90.00 0.9 3,656 3,358.60 3,316.22 43.84 88.60 3.9 3,749 3,424.25 3,381.87 46.34 87.90 2.7 3,842 3,487.68 3,445.30 47.53 86.90 1.5 3,935 3,550.72 3,508.34 47.53 87.20 0.2 4,029 3,614.77 3,572.39 45.88 87.70 1.8 4,122 3,680.11 3,637.73 45.80 87.40 0.2 4,216 3,743.69 3,701.31 48.24 90.50 3.6 4,310 3,803.31 3,760.93 53.54 86.70 6.41 4,404 3,858.69 3,816.31 53.84 86.40 0.4 4,497 3,914.37 3,871.99 52.55 87.00 1.5 4,590 3,972.36 3,929.98 50.36 86.00 2.5 4,683 4,031.85 3,989.47 50.20 86.50 0.5 4,775 4,092.02 4,049.64 48.58 87.00 1.8 4,870 4,154.69 4,112.31 48.17 87.60 0.6 4,961 4,216.01 4,173.63 47.86 88.90 1.1 5,053 4,277.60 4,235.22 47.63 89.20 0.4 5,148 4,341.67 4,299.29 47.66 90.30 0.9 5,240 4,403.88 4,361.50 47.16 89.70 0.7 5,334 4,467.79 4,425.41 46.71 92.40 2.2 5,428 4,532.24 4,489.86 46.71 92.90 0.4 5,521 4,595.63 4,553.25 47.35 91.00 1.7 5,613 4,657.60 4,615.22 48.14 90.30 1.0 5,707 4,720.43 4,678.05 47.84 89.40 0.8 5,802 4,784.37 4,741.99 47.82 89.70 0.2 5,894 4,846.26 4,803.88 47.43 90.30 0.6 5,973 4,899.81 4,857.43 47.65 91.20 0.9 6,080 4,972.21 4,929.83 47.65 90.90 0.2 6,174 5,035.29 4,992.91 47.90 88.30 2.1 6,268 5,096.89 5,054.51 49.91 85.70 3.0 6,362 5,157.71 5,115.33 49.56 82.40 2.7 6,455 5,220.33 5,177.95 45.85 80.20 4.4 6,547 5,284.48 5,242.10 45.36 81.00 0.8 6,641 5,349.64 5,307.26 47.24 82.80 2.4 6,734 5,411.60 5,369.22 49.27 81.90 2.3 6,826 5,471.75 5,429.37 48.38 80.80 1.3 6,919 5,534.65 5,492.27 47.55 78.30 2.2 7,011 5,595.97 5,553.59 47.76 78.00 0.3 7,104 5,658.44 5,616.06 47.82 78.10 0.1 7,196 5,720.08 5,677.70 48.64 79.40 1.4 7,290 5,782.80 5,740.42 47.12 80.50 1.8 7,383 5,847.21 5,804.83 45.98 78.70 1.9 7,476 5,912.00- 5,869.62 45.78 80.10 1.1 7,528 5,947.75 5,905.37 46.62 81.50 2.5 7,601 5,997.64 5,955.26 47.24 82.10 1.0 7,693 6,059.83 6,017.45 47.68 78.70 2.8 7, 786 6,122.24 6,079.86 47.89 76.10 2.1 674,971.9 675,039.9 675,109.7 675,181.1 675,249.4 675, 315.6 675,381.3 675,449.0 675,517.7 675,585.5 675,652.7 675,720.8 675,794.0 675,869.1 675,943.3 676,015.8 676,087.2 676,157.1 676,227.4 676,295.5 676,363.2 676,433.5 676,501.1 676,569.5 676,637.9 676,705.9 676,774.1 676,843.8 676,914.4 676,982.2 677,040.7 677,120.2 677,189.6 677.260.0 677.331.2 677.399.0 677.463.4 677.530.6 677.599.2 677.666.9 677,735.2 677,800.7 677 867.7 677 935.1 678,003.1 678,069.7 678,135.0 678,171.7 678,224.3 678,290.8 678,357.5 5,994,636.1 5,994,634.1 5,994,632.0 5,994,631.2 5,994,632.6 5,994,634.9 5,994,638.5 5,994,643.1 5,994,648.3 5,994,652.9 5,994,657.3 5,994,660.1 5,994,663.7 5,994,670.0 5,994,676.0 5,994,682.1 5,994,688.5 5, 994, 694.1 5, 994,699.1 5,994,702.7 5,994,705.4 5,994,707.4 5,994,709.0 5,994,709.3 5,994,707.7 5,994,707.0 5,994,707.8 5,994,709.6 5,994,711.8 5,994,713.4 5,994,714.0 5,994,714.4 5,994,716.5 5,994,721.9 5,994,731.0 5,994,742.9 5,994,755.1 5,994,766.3 5,994,777.2 5,994, 789.1 5,994,803.3 5,994,818.7 5,994,834.5 5,994,849.5 5,994,863.2 5,994,877.0 5,994,890.9 5,994,897.7 5,994,906.5 -5,994,919.4 5,994,935.9 Page 2 of 3 P 1-06_Directional_Surv. XLS MD TVD SS INCLINE AZIMUTH DOGLEG ASP X ASP Y 7,879 6,184.63 6,142.25 47.95 76.00 O. 1 7,971 6,246.88 6,204.50 47.48 75.50 0.7 8,065 6,309.91 6,267.53 47.58 74.90 0.5 8,157 6,371.96 6,329.58 47.39 74.40 0.5 8,249 6,434.53 6,392.15 47.75 73.90 0.6 8,343 6,496.94 6,454.56 48.13 74.20 0.5 8,435 6,559.16 6,516.78 47.20 77.30 2.7 8,528 6,622.38 6,580.00 46.76 77.10 0.5 8,620 6,686.35 6,643.97 46.16 80.00 2.4 8,711 6,749.24 6,706.86 45.90 80.30 0.4 8,803 6,812.58 6,770.20 47.68 79.60 2.0 8,896 6,875.03 6,832.65 47.68 79.10 0.4 8,988 6,936.82 6,894.44 47.29 78.30 0.8 9,081 7,000.96 6,958.58 46.17 78.70 1.2 9,173 7,065.32 7,022.94 45.28 78.00 1.1 9,266 7,130.12 7,087.74 45.98 78.60 0.9 9,361 7,193.97 7,151.59 49.31 81.30 4.1 9,457 7,256.60 7,214.22 49.19 82.00 0.6 9,552 7,319.14 7,276.76 48.44 82.20 0.8 9,646 7,381.83 7,339.45 48.56 79.40 2.2 9, 742 7,444.48 7,402.10 49.37 78.20 1.3 9, 837 7,507.04 7,464.66 48.40 77.90 1.1 9,932 7,568.90 7,526.52 50.27 79.80 2.5 10,028 7,630.57 7,588.19 50.15 79.80 O. 1 1 O, 123 7,691.67 7,649.29 49.19 79.60 1.0 10,218 7,754.41 7,712.03 48.97 79.40 0.3 10,314 7,817.68 7,775.30 47.89 79.80 1.2 10,409 7,881.24 7,838.86 48.66 80.10 0.8 10,505 7,945.14 7,902.76 47.70 80.130 1.0 ~ 10,599 8,008.02 7,965.64 48.42 80.40 0.8 10,695 8,071.55 8,029.17 48.91 80.40 0.5 10,791 8,135.03 8,092.65 48.05 80.30 0.9 10,886 8,197.97 8,155.59 48.39 81.00 0.7 10,981 8,261.09 8,218.71 48.58 80.70 0.3 11,076 8,324.61 8,282.23 47.92 80.90 0.7 11,172 8,389.47 8,347.09 46.76 81.00 1.2 11,267 8,455.64 8,413.26 44.80 80.60 2.1 11,362 8,524.08 8,481.70 43.74 80.30 1.1 11,458 8,593.28 8,550.90 43.31 79.70 0.6 11,534 8,649.60 8,607.22 41.18 79.39 2.8 11,554 8,664.38 8,622.00 40.63 79.30 2.8 11,647 8,735.75 8,693.37 39.97 79.00 0.7 11,725 8,795.67 8,753.29 39.41 79.10 0.7 11,831 8,877.63 8,835.25 39.60 80.00 0.6 11,925 8,949.62 8,907.24 39.80 79.40 0.5 11,978 8,990.22 8,947.84 40.10 78.40 1.3 12,050 9,045.48 -.9,003.10 40.10 78.40 0.0 12,092 9,077.94 9,035.56 39.77 78.40 0.8 12,183 9,147.63 9,105.25 39.77 78.40 0.0 678,424.2 678,490.1 678,556.3 678,621.1 678,686.5 678,752.5 678,818.3 678,884.0 678,949.6 679,013.6 679,079.7 679,146.7 679,212.5 679,278.9 679,343.3 679,407.8 679,476.5 679, 548.1 679,618.7 679,688.3 679,758.6 679,828.3 679,898.6 679,971.2 680,041.7 680,112.5 680.182.3 680252.2 680.322.2 680390.9 680.461.8 680 532.2 680,601.4 680.671.6 680 741.5 680 810.8 680 877.6 680 943.1 681,007.6 681,057.6 681,070.2 681,129.3 681,177.9 681,244.1 681,302.6 681,335.8 681,381.2 681,407.6 681,464.2 5,994,954.2 5,994,972.6 5,994,991.7 5,995,011.1 5,995,031.4 5,995,051.9 5,995,070.3 5,995,086.8 5,995,101.7 5,995,114.4 5,995,127.7 5,995,141.9 5,995,156.7 5,995,171.8 5,995,186.6 5,995,201.6 5,995,215.4 5,995,227.6 5,995, 239.1 5,995,252.0 5,995,267.7 5, 995, 284.1 5,995,299.7 5,995,314.5 5,995,329.0 5,995,343.9 5,995,358.4 5,995,372.4 5,995,386.4 5,995,399.9 5,995,413.6 5,995,427.3 5,995,440.4 5,995,453.3 5,995,466.3 5,995,479.0 5,995,491.5 5,995,504.1 5,995,517.0 5,995,527.4 5,995, 530.1 5,995,542.9 5,995,553.5 5,995,567.3 5,995,579.3 5,995,586.6 5,995,597.1 5,995,603.1 5,995,616.1 Page 3 of 3 P,¢fcrcr~ 'vVortd ~es:. ~ "/0.23.27 lq- Long. 14834,54 I~¢t'¢rcnc~ CRID System: Ah.~tStatc Pttmc Zone: Ah~ 4 l~t'~rcnce CRID Coordint~: (1t): 59945S3.63N 674346,08E · "~rth Aligned To: TRUE NORTH' v,v ..t~,~.. :..~. ...... Halliburton Energy Services - Drilling Systems PSL Survey.RePOrt. . , . .VeStal S~ka Plane: S~.~ d~. .- · . * ; ,.... z .... . . ]ob No: 00258 D'~: Ti=~: 3:30 pm WelIl~t~ ID: PI~ Dm Cr~: 8/9/96 .' . ~oo' "o:oo ".0.o0 '4z~o' · 'o.6o,: o.0o' o:o0' o:ooN" "'o.~ot~' ~. 0.00~...0.oo .... y~.63,674~:o~,.· '~o ""0'.0' '~'~0~' '.'';:"::' ...... ' ~.x #] 1 ].500 B,H. { S 1/2" HCLE } ' ' 50.00 0. t0 129.40 -7.20 '50.00 0.03 50.00 0.035 0.03E '0:'04~'~.129.40" 5994583.61 674346, ii'0.20 0,1 BPHG.PBD ::.~- .. . .....,~, i~.00 0.00 '0.00 -57.20 100.00 0.06 50.00 0.06 S O.07E 0.0~129.40 5~8.t.58 67~346.15' 0.20' ;50.00 0.20 144,30 407;10 1'50.00 0.10 50.00 0.13 S 0.12E 200,00 .0.2095.9~ -137.20 Z00.O0 0.2.1 50.00 0.21S 0.26E 250.00 0.30 5530 -207.20 250.00 0.43 50.00 0.148' :0.45E 0..1'}~i3&85' 599458331 67~3'46.20 · 0.33~128.8~. 5994583.43 67434634 0.4~107,33 5994~.50 67¢346.53 0.40, 0.4 tlPHG-PBD 0.33 0.6 BPHG-PBD 0.39 0.8 t~HG-PI3D 300.00 0.40 72.10 45~,20 300,00 0,'/2 3~,00 0,60 77.80 '-307.20 350,1)0 1.15 :[00.00 0.60 33.20 457.19 399.99. 1.58 450.00 t,00 11.50 407.19 449.99 1.89 500.00 1.50 20.50 -457.18 499.98 233 550.00 2.60 27,90 -507.14. 549.94 3.28 ~00,00 3.50 3430 -557,07 59937 4.95 50.00 0.01 S 0.72E 50.00 0,101'4' 1.15E ., 50.00 0.37N 1.55E' , . 50~00 1.02N ' 1.78E 50.00 2,06N 2.09E 50.O0 3.67N 2.85E 50.O0 ,5,93N 4.25E 1.1.~ 85.18. 5~5~,% 674347~ Ls~ 76,50 ' 5~.04 674347.62 . , zo~'~0~19, s~.6~ 2.~ 45.47 59~.74 6743~.12 : Z~ 35.~ 59~5~.~ 6743~.19' , , 0.41 0.9i O.99 1.07 2.26 0.9 BPHG-PBD 12 BPHG-~D !.6 BPIIG.PBD 2.1. 2.6 3.7' 4.7 BPHG-PBD BPHG-PBD Halliburton. Energy Services - Drilling Systems PSL Survey Report WcUpa~ U):. ?1~ I O O~ I h- Z CD )- CD ~c~ Ind ~ Subs~a TVD V~cal ~ TOTAL ~l~sute GRID ~xx~di~ (n) (n) (n) (~) .ca) Sun,~ Tool 650.00 5.20 28.20 -606.93 649.73 7.27 50.00 9.18N " 6.20E ' 11,0'/~ 34.02 5994592..96 6?4352.06 334 6.5 BPHG-?BD 700.00 '/.0018.50 -656.64 699.44 ' 9.89 50.00 '14.078 8.23E 16.30~' 30.34 5994597.89 674353.98 4.14 8.5 ~EC,-PBD 750.00 6.30 12.50 .706.31 749.11 12.13 · ~.00 19.638 9.79E 21.94~ 26.51 5994603.49 674355.41 1.97 9.5 ]3PEG.BBD · 793.00 5,90 12.20 -749.06 791,86 13.64 43,00 24.108 10,77E . 26,4~'24.0~ 5994607,9~ 674356.29 0,93 9,9 13PHG.I:'BD 8~,92 5.65 14.70 -82&58 871.38. 16.45 79,92 3L928 12,64£ 34,33(~ 21.60 5994615.84 674357.~/ 0.44 10.3 961.93 4,74 15.50 -917.22 960.02 19.49 89,01 39,708 14.~E 4235~ :20,36. 599'4623.66 674389.88 1.03 11.2. BPHM.~D ,._:~ 11~1,46 2.05 5930 ,1.096,531139.33:,. 24.34 ... 99_,.46. 46:868... 18.,74,E.. 50.4.~ 2L...79..... 5.,~fO,9! 674363...T2, ..... t.N, . .15.0 , .BPE]v[-PBD .... .... .~.=~2,=.;=~-~ ..... .--~..?.,. -~-? ,..C??~? ~: .,..~.~-,~.. · .j~,?/~.-?..--- .............. ~x,..-.--.~ ......... - >.-,.~,.-.~.~- ~-.=~.~.,r~- :,, .- -..,: ....... ~ · '~ ....,..~. ...................... ~.... ~?~'.~.-.: '.....' ....... .'~, ...: ' .. ~ : .:. · . · ': . · .",': .' -. ':, ~: L ?d :..% ~.' -' ..' .'.~T . , '.:.... a~.,' , . ...... ...... . ...... . ...... '. :'. '.;c..: . · .... j~; ~.;..'. ~'.', -~ ' · :.. ,'.~: :.: ::: . ':'2" .'-." ~'. "~.~'. ':.' .'. :hal .:... .-- :.:..'. : ...... .~ · .~, ...... a ... .~. , . . .. ~ .... .... · 1~26.~8.. 2.50 .62.00..' :..L731.~ :.' ?.1324~0 '.'.F ' 3t34..'. ~t8 ~$$1q. · .25~B.:' ~ 56..~ 26.61 :~ d. 5~34~.76 674300~f:: : ":0.12- -. <15.5' .. ]3l:~.t:~ · . ." ..:. ':.: .',' :1420,65 · 3.5369.90..1375,44" '1~l&24 36.06 93.8'/ $2.518 29,85E .60,40~..-29.,62: . .59946,~632 674374.70:' '. t..l$ ,.. 1..6,6 .. ~.Pl~. .1512.85 433' 76.00 ,.1467~3~ :' '1310.19 ~i68 92.20 ~4.428 36~28R 65A!{~ 35,69, $~946~.98 674381.08 1,49 l&0 BPHM, t~ ' . 1606,22 6,?6 87,60.. -1560.25 .1603.~ 52.06 93.37 $5.~H 4S:59]q. .71,.90~ 39.3~ , .~t~94640,2~ 674390..36 2.41 20.2 BPHM~ 1699.39 7.81 89,60 -16~Z70' 1695.~' 6).~ 93.17, ~.SgN .$?..4OE ' ~.11~45.77 $994640.~ 674402.16 1.16 213 BPHM-I:~D '. ' .... :' ''. '" -." ' :.,"-,' "{ ~: '-';'. · ~"2,'; ''''; .... -.... ..,....: ...., ::.. .:..,;..~ .. ...; . :' .a ......... ' ................................ :, ................................... ..'. ." 1882,55 9,29 94,90 21834,01 lg/6. gl 8937 '9~0) 54.75N' ,83,~..E 99,67~6.68 ~99464031 6744~.06 1,'/~ 233 BI~I~M~ ']97~:~s · '10:~s' 9~:~0.~ "1~,~' '.u~.~ '.:' ~tos:no 9~20~,'"'9~N"' ~.',f~,' .u:~:0~'~r,7~ .'." '""."~..~' 6~4~'; "':" {;al" ~.' '~.0' "~" "':.."' '." "" ~06s.87 lZ7493.~0 .20]~,89 ~0~.69 lZ,,z~' 93.~2 ~2.88N l~&?o~ 129.7~g c~.1~ 899,~38.76 674,~.~ 1.92 26.s ., ..,,. 2162,67 ~5,53 94.80 .2107.84 2150.64 146.6'/ 93.~ 50.~N 141.54E 1~0.32,~ ~0.31' 599463?.56 674486.39 2.99 29.6 B~-PBD '"' 225'/,55t8,79 9'/.20-2198.48 2241.28 17~.92 ~4,~ 47.66N 16936E 17~.9~ 74.28 5994635.23 67451'4.27 3.52 32.9 BPI~'~.I~D 2350,00 19,~ 96.80 .2285,83 2328.63 203.31 92.45 43.97N 199A2E 204.21~ TLS.7 5994632.24 674.544.41 0.?4 .33.6 ~I-~f-PBD " 2442,46 2i.10 93.60 2538.35 24.12 89,40 2630.61 28,16 89.20 2723.09 28.91 90.00 2816,41 31,02 89.80 2909.55 34,06 89.70 3002,87 38,10 ~)1.10 3094.61 40.3'/92.60 3189,77 44.83 93.50 -2372.56 2415.36 234.62 92.46 41.108 .~I.07 2~03.Sa Z71.07. 0S.a9 .2543.88 , 2586.68 3il.46 92.26 40.738 -2'/84.48 2827.28 .2a59.88 2902.68 505.~2· 93.3.'2 -2930,94 29'/3,74 563,1491.74 -3000.~7 3043.7'/ ~&~3 95.16 41.O3N 41.1!I'4 41,338 231.33E 268.1~E 30~.79E 399.58E 449.67E 504.61 E 562.60E '., 234.9~ 79.92 271.16~ 8lA? '311.4~ 82.49 4o1.6~ · . 8337. ~13. ~4.75 16.03 $994630.12 6'/4576.37 ZI4 $~31630~I0 674613.21 3.S~ , ~.~31.$~ 6744~332 4.3~ ,.. $9~t463Z89 674697.97 0.gz 5~6.82 67~9.~ . 4.42 35.6 13PlLM-PBD 39.0 BPHIv[.PBD 43.0 BPI-~VI-H3D 43.9 BPHM-PBD 46.0 BPHM-t'i~ 49.0 BPHM-PBD $3.2 . BPHM.~D "' S$.6 Bln{]v[-PBD 60.! BtSIM-PBD Halliburton Energy Services - Drilling Systems PSL Survey Report ~ Ind DriR Sulks' TVD VerticalC4xu~. TOTAL' C~ (~) (~) (~) (n) (n) (n) (n) (~ (n) (~) (~) 32~.20 48,53 92.~ -3065.~ 3107. g 693,4~ 93.43 31,98N 6~,76E 695,~~6 3375.95 49.29 93.~ -3126.~ 316~ 762,~ 9~75 28~N 7~.57E 765.~.~. 3~71.~ 48.11 ~,~ -31~.76 3231.~ 832.78 95.~ ~.SIN ~5.91E 8363~ ~3 otun~ uts cm · . (ii) (~ (dg/lOOfl) (&g) fg94631.84 6?5039;86 4.02 63.9 l~~ ~t6~.7~ 678to~.'/3 I. I0 64.9 5~628.97 675181.11 2.75 672 Surv~' Tool 3563,24 47.32 90.00 -3250.82 3293.62. 900.4"/ 92.24 25.5'7N 904.1:5E 904.51~ 8~g 599463033 675249,33 0.91 ' 633 BPHM-PBD ]656.02 43.84 88,60 -3315.75 3358.55 966.32 92,78 26,36N 970.40E 970,76~8~,44. 5994632.67 675315154 3.~0 72.0 B~ 3749.02 '46.3487.90 -3381.40 342420 1031.89 93.00 253{N 1036.23E' !036.62~ 88.43 599463623 675381.29 2.74 74.5 BFHM~ 3841.92 47.53 86,90 -3444.84.3487.64 1099,56 92.~0' 31.46N 1104.03E 1104.4'F~8837 5994640.91 675449,00 1,50 75.9 BH{M-FBD '' " 88 .... '-~ 3.935.:29 47.53. ~,~ -3207.8a.:$~..68 ..1.1.~.~6. 9.3.,5.7. 35.~N. 11.7~.1~ .1)~.3.~. 59, ....5~~..6~517,67.. .. o.2.4 ..'/6..1 .... BY..I~i.~. '" ; ............ .d' ~' .T'..' ..... ~,. ' '.~..V.. ;'..;~ " '';.~. -e.~.,, '. .' ~-,", · if,"..', .,. ':.,. .. 3, , '. .,..'. ~ .' .... '..- '., .~'"2': . '. '- · · ,,,- ' ¢'- .'Y"""''''~ .. ,'. ' ",.' · ::. 'r:'-' .' '' .'; ....... ,:.;. ~.... ..' ,.=.~k.' ~.-. ),.'..'., ;,'.,.. 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E 6273,48E, 6343.88E 730.96N ?4L0.tN 6414.13E .. 631333~ 83,56 63~4.5~ 83.53 65Zi,!rfa S3.47 5995386.38, 680321,44, 1.00 165.9 B.PIIM4aBD ' 5995399.95 680390,09 , 0.83 167.7 ~-?BD 5995413.70 6804~,~ 0.51 168~ BIStM-PBD 5995427.43 680531,36 0.90 t69.0 , BP~.-PBD 5595440.55 680600.57 0,66 1.69.7 BPHM-PBD 5995453.58' 680670,67 031 170.0 5995466.66 680740.63 0,71 170.6 ~-~D 5~47~.41 680~.86' 121 "'171.8 BPttM-PBD '5~95491.89, 680876,69 2,09 " L73.8 BH-IM-HK) Halliburton Energy Services, Drilling Systems PSL Su . ep rt 1~ ~5~ W¢llt~th ID: ?I-06MWD ~ I~ D~ ~1~::~ TVD Vc~i~ Coom TOTAL C~ (a) (~) (~.) (~) (a) (a) (~) (~) (~) (~). (~) 11362.4? 43.74 ~.30 ~481.36' 8524.16 6~.31 '9538 76~.~N .6616.~E ~.5~83.$1 11457.91 43.31 79.70 45~.~ 8593.~ 6~.95 95.g ~538N ~i.~E .6726.1~ 83.~ 11553.55 40.~ 79.30 ~621.~ ~.~ 6~9.79 '95.~ ~7.03N 67~.18E- .6789.~83.34 599553069 63106~.21 11649.13 39.9'/79.00 .8~594.$$8737.35 6851.48 95.58 798.$?N '6g04.90E ~1.6~ ~.31 · 5~3.79 ~1129.~ z 1i~5.~ 39.41 ~9.10.4751.~ ~95.~3 6~9.8~ ~.~ ~.~ 6~Z~ 6~.~ 83.~ 59~.15 ~117~'~ ~ lig31.~ 39.~ ~.00 -~4.~ ~.69 6~7.27 1~.22 '~.I3N 6918.~E. 6~7.3~ 83.24 · 5~01 ~1243.~ ~ . ~1924,~ 39.~ ~.~ 4~7.~ 89~.I0 '70~,45 ~.Sg ~.~N 6~.~B 7~6.5~'~21" ~.01~I~I,B 1.13 174.9 BPHM-PttD 0.62 175.5 B?I-]M-?I~D 2.81 17~.1 BPHM-E~D 0.'73 1'78.8 BPI-ZM-~D 0.74 179.4 B.P~UVI-PBD 0.5"/ 180.0 BPI. UVl.-PBD 0.'/6 180.7 BPHM~ Tool 2.40. 182.0 BPHM4:gD Well Gpma Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 P1-06 Pl-06 P1-06 Pl-06 Pl-06 Pl-06 P1-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 P1-06 Pl-06 Pl-06 P1-06 Pl-06 Pl-06 P1-06 Pl-06 Pl-06 Pl-06 Pl'06 Pl-06 Surv Dpth Md O. 50. 150. 200. 250. 300. 350. 400. 450. 500. 550. 600. 650. 700. 750. 793. 872.92 961.93 1,051. 1,141.46 1,233.6 1,326.78 1,420.65 1,512.85 1,606.22 1,699.39 1,790.52 1,882.55 1,975.55 2,068.87 2,162.67 2,257.55 2,350. Surv Dpth Tvd Azimuth 0. 50. 150. 200. 250. 300. 350. 400. 450. 499.99 549.96 599.89 649.74 699.46 749.12 791.88 871.39 960.03 1,048.94 1,139.34 1,231.41 1,324.51 1,418.25 1,510.2 1,603.09 1,695.51 1,785.8 1,876.82 1,968.37 2,059.7 2,150.65 2,241.3 2,328.65 P1-06 Survey Incline 0. 129.4 144.3 95.9 55.3 72.1 77.8 33.2 11.5 20.5 27.9 34.8 28.2 18.5 12.5 12.2 14.7 15.5 30.3 59.3 60.7 62. 69.9 76. 87.6 89.6 92.5 94.9 93.4 93.8 94.8 97.2 96.8 Radius o. 0.1 0.2 0.2 0.3 0.4 0.6 0.6 1. 1.5 2.6 3.5 5.2 7. 6.3 5.9 5.65 4.74 2.06 2.05 2.37 2.5 3.53 4.83 6.76 7.81 7.72 9.29 10.95 12.74 15.53 18.79 19.46 Map Dx o. 0.04 0.3 0.46 0.58 0.81 1.22 1.64 2.07 2.92 4.63 7.27 11.04 16.26 21.9 26.35 34.28 42.29 47.53 50.41 53.25 56.46 60.31 65.32 71.83 80.04 89.15 99.63 113.06 129.73 150.32 175.94 204.22 Map Dy O. 0.03 0.21 0.35 0.54 0.8 1.22 1.61 1.83 2.12 2.85 4.19 6.06 7.98 9.41 10.29 11.97 13.88 15.56 17.71 20.75 24.18 28.65 35.03 44.31 56.11 68.43 82.02 98.35 117.49 140.36 168.25 198.38 O. -0.03 -0.23 -0.3 -0.23 -0.09 Surv Dx 0.03 0.31 0.96 2.01 3.65 5.94 9.23 14.17 19.77 24.26 32.12 39.94 44.91 47.2 49 04 51 02 53 07 55 13 56 53 57 07 57 14 56 56 55.77 55. 53.8 51.47 48.48 Surv Dy O. 0.03 0.2 0.34 0.53 0.8 1.22 1.62 1.85 2.17 2.93 4.33 6.27 8.31 9.87 10.85 12.72 14.81 16.6 18.81 21.89 25.36 29.88 36.31 45.62 57.43 69.74 83.32 99.62 118.74 141.58 169.4 199.46 X Loc Y Loc O. 674,346.01 5,994,586.07 -0.03 674,346.04 5,994,586.04 -0.23 674,346.22 5,994,585.84 -0.31 674,346.36 5,994,585.77 -0.24 674,346.55 5,994,585.84 -0.11 674,346.81 5,994,585.98 O. 674,347.23 5,994,586.1 0.27 674,347.62 5,994,586.38 0.92 674,347.84 5,994,587.03 1.96 674,348.13 5,994,588.08 3.58 674,348.86 5,994,589.72 5.84 674,350.2 5,994,592.01 9.09 674,352.07 5,994,595.3 13.98 674,353.99 5,994,600.24 19.55 674,355.42 5,994,605.84 24.01 674,356.3 5,994,610.33 31.83 674,357.98 5,994,618.19 39.61 674,359.89 5,994,626.01 44.54 674,361.57 5,994,630.98 46.77 674,363.72 5,994,633.27 48.54 674,366.76 5,994,635.11 50.44 674,370.19 5,994,637.09 52.39 674,374.66 5,994,639.14 54.3 674,381.04 5,994,641.2 55.48 674,390.32 5,994,642.6 55.75 674,402.12 5,994,643.14 55.53 674,414.44 5,994,643.21 54.63 674,428.03 5,994,642.63 53.46 674,444.36 5,994,641.84 52.25 674,463.5 5,994,641.07 50.51 674,486.37 5,994,639.87 47.53 674,514.26 5,994,637.54 43.84 674,544.39 5,994,634.55 Page 1 Well Gpma Pl-06 P1-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 P1-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 P1-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 P1-06 P1-06 Surv Dpth Md 2,442.46 2,538.35 2,630.61 2,723.09 2,816.41 2,909.55 3,002.87 3,094.61 3,189.77 3,283.2 3,375.95 3,471. 3,563.24 3,656.02 3,749.02 3,841.92 3,935.29 4,028.69 4,122.48 4,215.73 4,310.25 4,403.77 4,496.71 4,589.78 4,682.88 4,775.32 4,869.66 4,961.33 5,052.93 5,148.02 5,239.94 5,333.52 5,427.51 5,520.5 5,612.66 Surv Opth Tvd Azimuth 2,415.38 2,503.9 2,586.71 2,667.96 2,748.8 2,827.31 2,902.73 2,973.79 3,043.82 3,107.91 3,168.87 3,231.61 3,293.67 3,358.6 3,424.25 3,487.68 3,550.72 3,614.77 3,680.11 3,743.69 3,803.31 3,858.69 3,914.37 3,972.36 4,031.85 4,092.02 4,154.69 4,216.01 4,277.6 4,341.67 4,403.88 4,467.79 4,532.24 4,595.63 4,657.6 Incline Radius 93.6 21.1 234.97 89.4 24.12 271.18 89.2 28.16 311.5 90. 28.91 355.38 89.8 31.02 401.72 89.7 34.06 451.6 91.1 38.08 506.29 92.6 40.37 563.97 93.5 44.83 627.93 92.6 48.53 695.52 93.5 49.29 765.11 90.4 48.11 836.33 90. 47.32 904.54 88.6 43.84 970.78 87.9 46.34 1,036.64 86.9 47.53 1,104.5 87.2 47.53 1,173.36 87.7 45.88 1,241.33 87.4 45.8 1,308.6 90.5 48.24 1,376.8 86.7 53.54 1,450.09 86.4 53.84 1,525.42 87. 52.55 1,599.81 86. 50.36 1,672.57 86.5 50.2 1,744.14 87. 48.58 1,814.3 87.6 48.17 1,884.82 88.9 47.86 1,952.96 89.2 47.63 2,020.74 90.3 47.66 2,090.98 89.7 47.16 2,158.61 92.4 46.71 2,226.87 92.9 46.71 2,295.08 91. 47.35 2,362.99 90.3 48.14 2,431.15 Map Dx Map Dy 230.35 267.19 307.81 351.97 398.57 448.64 503.56 561.57 625.93 693.86 763.73 835.11 903.34 969.55 1,035.32 1,103.03 1,171.71 1,239.53 1,306.66 1,374.81 1,448.01 1,523.11 1,597.28 1,669.8 1,741.14 1,811.08 1,881.43 1,949.47 2,017.22 2,087.46 2,155.11 2,223.46 2,291.86 2,359.89 2,428.1 46.35 46.33 47.78 49.11 50.28 51.67 52.53 51.99 50.04 48.02 45.93 45.15 46.5 48.83 52.39 57.05 62.19 66.8 71.25 74.05 77.64 83.93 89.95 96.07 102.42 108 03 112 99 116 66 119 36 121 31 122 89 123 23 121 67 120 94 121 76 Suw Dx 231.37 268.2 308.84 353.02 399.63 449.72 504.65 562.63 626.93 694.79 764.59 835.94 904.18 970.43 1,036.26 1,104.06 1,172.84 1,240.75 1,307.97 1,376.16 1,449.43 1,524.65 1,598.94 1,671.59 1,743.05 1,813.11 1,883.55 1,951.66 2,019.45 2 089.72 2 157.39 2 225.73 2 294.07 2 362.07 2 430.28 Surv Dy X Loc Y Loc 40.97 674,576.36 5,994,632.42 40.09 674,613.2 5,994,632.4 40.59 674,653.82 5,994,633.85 40.89 674,697.98 5,994,635.18 40.97 674,744.58 5,994,636.35 41.19 674,794.65 5,994,637.74 40.77 674,849.57 5,994,638.6 38.88 674,907.58 5,994,638.06 35.43 674,971.94 5,994,636.11 31.83 675,039.87 5,994,634.09 28.11 675,109.74 5,994,632. 25.66 675,181.12 5,994,631.22 25.42 675,249.35 5,994,632.57 26.21 675,315.56 5,994,634.9 28.23 675,381.33 5,994,638.46 31.31 675,449.04 5,994,643.12 34.85 675,517.72 5,994,648.26 37.88 675,585.54 5,994,652.87 40.76 675,652.67 5,994,657.32 41.97 675,720.82 5,994,660.12 43.85 675,794.02 5,994,663.71 48.39 675,869.12 5,994,670. 52.68 675,943.29 5,994,676.02 57.11 676,015.81 5,994,682.14 61.79 676,087.15 5,994,688.49 65.77 676,157.09 5,994,694.1 69.09 676,227.44 5,994,699.06 71.17 676,295.48 5,994,702.73 72.29 676,363.23 5,994,705.43 72.6 676,433.47 5,994,707.38 72.6 676,501.12 5,994,708.96 71.35 676,569.47 5,994,709.3 68.19 676,637.87 5,994,707.74 65.88 676,705.9 5,994,707.01 65.11 676,774.11 5,994,707.83 Page 2 WellGpma Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 P1-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 P1-06 P1-06 Pl-06 Pl-06 Pl-06 P1-06 Pl-06 P1-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Su~ Dp~ Md 5,706.54 5,801.78 5,893.61 5,972.93 6,080.41 6,174.26 6,267.97 6,362.06 6,455.13 6,546.83 6,641.14 6,734.2 6,825.56 6,919.49 7,010.52 7,103.5 7,196.03 7,289.54 7,383.2 7,476.26 7,527.91 7,600.96 7,692.93 7,785.81 7,878.91 7,971.43 8,064.78 8,156.6 8,249.34 8,342.5 8,434.87 8,527.53 8,620.39 8,710.97 8,803.48 Su~ DpthTvd Azimuth 4,720.43 4,784.37 4,846.26 4,899.81 4,972.21 5,035.29 5,096.89 5,157.71 5,220.33 5,284.48 5,349.64 5,411.6 5,471.75 5,534.65 5,595.97 5,658.44 5,720.08 5,782.8 5,847.21 5,912. 5,947.75 5,997.64 6,059.83 6,122.24 6,184.63 6,246.88 6,309.91 6,371.96 6,434.53 6,496.94 6,559.16 6,622.38 6,686.35 6,749.24 6,812.58 Incline 89.4 89.7 90.3 91.2 90.9 88.3 85.7 82.4 80.2 81. 82.8 81.9 80.8 78.3 78. 78.1 79.4 80.5 78.7 80.1 81.5 82.1 78.7 76.1 76. 75.5 74.9 74.4 73.9 74.2 77.3 77.1 80. 80.3 79.6 Radius Map Dx Map Dy Su~ Dx 47.84 2,500.88 2,497.83 123.57 2,500.03 47.82 2,571.46 2,568.39 125.76 2,570.62 47.43 2,639.28 2,636.21 127.35 2,638.46 47.65 2,697.75 2,694.72 127.94 2,696.97 47.65 2,777.12 2,774.15 128.33 2,776.39 47.9 2,846.59 2,843.6 130.44 2,845.87 49.91 2,917.17 2,914.01 135.81 2,916.38 49.56 2,988.72 2,985.2 144.91 2,987.77 45.85 3,057.01 3,052.98 156.86 3,055.81 45.36 3,121.94 3,117.36 169.07 3,120.45 47.24 3,189.71 3,184.61 180.23 3,187.95 49.27 3,258.8 3,253.19 191.08 3,256.76 48.38 3,327.11 3,320.91 203. 3,324.74 47.55 3,396.15 3,389.2 217.24 3,393.34 47.76 3,462.53 3,454.71 232.59 3,459.19 47.82 3,530.49 3,521.73 248.42 3,526.57 48.64 3,598.74 3,589.08 263.45 3,594.25 47.12 3,667.56 3,657.07 277.15 3,662.54 45.98 3,734.99 3,723.64 290.97 3,729.41 45.78 3,801.23 3,788.99 304.79 3,795.07 46.62 3,838.31 3,825.64 311.6 3,831.87 47.24 3,891.49 3,878.27 320.44 3,884.69 47.68 3,958.84 3,944.78 333.3 3,951.48 47.89 4,026.76 4,011.53 349.87 4,018.6 47.95 4,094.76 4,078.19 368.09 4,085.66 47.48 4,162.1 4,144.11 386.48 4,152. 47.58 4,229.75 4,210.26 405.62 4,218.57 47.39 4,296.17 4,275.09 425.05 4,283.84 47.75 4,363.27 4,340.49 445.28 4,349.69 48.13 4,431.08 4,406.53 465.84 4,416.19 47.2 4,498.41 4,472.28 484.2 4,482.35 46.76 4,565.51 4,537.97 500.74 4,548.41 46.16 4,632.39 4,603.6 515.65 4,614.37 45.9 4,697.35 4,667.55 528.29 4,678.6 47.68 4,764.53 4,733.65 541.61 4,744.99 Surv Dy X Loc 65.29 676,843.84 65.84 676,914.4 65.84 676,982.22 65.07 677,040.73 63.61 677,120.16 64.1 677,189.61 67.82 677,260.02 75.26 677,331.21 85.63 677,398.99 96.33 677,463.37 · 105.92 677,530.62 115.17 677,599.2 125.51 677,666.92 138.15 677,735.21 151.97 677,800.72 166.23 677,867.74 179.69 677,935.09 191.8 678,003.08 204.06 678,069.65 216.35 678,135. 222.31 678,171.65 229.92 678,224.28 241.22 678,290.79 256.23 678,357.54 272.89 678,424°2 289.74 678,490.12 307.33 678,556.27 325.25 678,621.1 343.95 678,686.5 362.96 678,752.54 379.78 678,818.29 394.79 678,883.98 408.16 678,949.61 419.31 679,013.56 431.08 679,079.66 Y Loc 5,994,709.64 5,994,711.83 5,994,713.42 5,994,714.01 5,994,714.4 5,994,716.51 5,994,721.88 5,994,730.98 5,994,742.93 5,994,755.14 5,994,766.3 5,994,777.15 5,994,789.07 5,994,803.31 5,994,818.66 5,994,834.49 5,994,849.52 5,994,863.22 5,994,877.04 5,994,890.86 5,994,897.67 5,994,906.51 5,994,919.37 5,994,935.94 5,994,954.16 5,994,972.55 5,994,991.69 5,995,011.12 5,995,031.35 5,995 051.91 5,995 070.27 5,995 086.81 5,995 101.72 5,995 114.36 5,995 127.68 Page 3 Well Gpma Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 P1-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 P1-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 P1-06 Pl-06 P1-06 Pl-06 Pl-06 Pl-06 Pl-06 Pl-06 P1-06 Pl-06 P1-'06 Surv Dpth Md 8,896.23 8,987.66 9,081.24 9,173.43 9,266.1 9,360.88 9,456.83 9,551.81 9,646.41 9,741.84 9,836.98 9,931.91 10,028.27 10,122.68 10,218.46 10,313.82 10,409.32 10,505.15 10,599.23 10,695.42 10,791.19 10,885.66 10,980.89 11,076.29 11,172.01 11,266.89 11,362.47 11,457.91 11,534. 11,553.55 11,647.13 11,725. 11,831.23 11,924.8 11,977.76 Surv Dpth Tvd Azimuth 6,875.03 6,936.82 7,000.96 7,065.32 7,130.12 7,193.97 7,256.6 7,319.14 7,381.83 7,444.48 7,507.04 7,568.9 7,630.57 7,691.67 7,754.41 7,817.68 7,881.24 7,945.14 8,008.02 8,071.55 8,135.03 8,197.97 8,261.09 8,324.61 8,389.47 8,455.64 8,524.08 8,593.28 8,649.6 8,664.38 8,735.75 8,795.67 8,877.63 8,949.62 8,990.22 Incline 79.1 78.3 78.7 78. 78.6 81.3 82. 82.2 79.4 78.2 77.9 79.8 79.8 79.6 79.4 79.8 80.1 80. 80.4 80.4 80.3 81. 80.7 80.9 81. 80.6 80.3 79.7 79.39 79.3 79. 79.1 80. 79.4 78.4 47.68 47.29 46.17 45.28 45.98 49.31 49.19 48.44 48.56 49.37 48.4 50.27 50.15 49.19 48.97 47.89 48.66 47.7 48.42 48.91 48.05 48.39 48.58 47.92 46.76 44.8 43.74 43.31 41.18 40.63 39.97 39.41 39.6 39.8 40.1 Radius 4,832.81 4,899.83 4,967.59 5,033.21 5,099.08 5,168.89 5,241.5 5,312.93 5,383.64 5,455.3 5,526.58 5,598.28 5,672.12 5,743.89 5,816.06 5,887.2 5,958.32 6,029.59 6,099.44 6,171.54 6,243.13 6,313.48 6,384.71 6,455.81 6,526.13 6,594.05 6,660.67 6,726.28 6,777 32 6,790 09 6,850 45 6,900 04 6,967 48 7,027 14 7,061 05 Map Dx 4,800.73 4,866.5 4,932.93 4,997.25 5,061.79 5,130.44 5,202.1 5,272.65 5,342.29 5,412.56 5,482.31 5,552.61 5,625.15 5,695.64 5,766.48 5,836.33 5,906.2 5,976.23 6,044.9 6,115.81 6,186.2 6,255.42 6,325.54 6,395 51 6,464 75 6,531 59 6,597 11 6,661 55 6,711 62 6,724.15 6,783.3 6,831.89 6,898.05 6,956.59 6,989.8 Map Dy Suw Dx Suw Dy X Loc Y Loc 555.85 4,812.39 443.75 679,146.74 5,995,141.92 570.58 4,878.48 456.95 679,212.51 5,995,156.65 585.73 4,945.25 470.54 679,278.94 5,995,171.8 600.56 5,009.9 483.87 679,343.26 5,995,186.63 615.5 5,074.77 497.3 679,407.8 5,995,201.57 629.28 5,143.72 509.48 679,476.45 5,995,215.35 641.52 5,215.64 520.04 679,548.11 5,995,227.59 653. 5,286.44 529.87 679,618.66 5,995,239.07 665.95 5,356.37 541.2 679,688.3 5,995,252.02 681.59 5,426.98 555.19 679,758.57 5,995,267.66 698.06 5,497.1 570.03 679,828.32 5,995,284.13 713.61 5,567.74 583.94 679,898.62 5,995,299.68 728.42 5,640.61 597.05 679,971.16 5,995,314.49 742.94 5,711.42 609.92 680,041.65 5,995,329.01 757.78 5,782.58 623.11 680,112.49 5,995,343.85 772.29 5,852.75 635.99 680,182.34 5,995,358.36 786.37 5,922.93 648.43 680,252.21 5,995,372.44 800.34 5,993.27 660.77 680,322.24 5,995,386.41 813.86 6,062.23 672.68 680,390.91 5,995,399.93 827.56 6,133.44 684.72 680,461.82 5,995,413.63 841.22 6,204.13 696.74 680,532.21 5,995,427.29 854.28 6,273.64 708.18 680,601.43 5,995,440.35 867.26 6,344.04 719.52 680,671.55 5,995,453.33 880.27 6,414.3 730.9 680,741.52 5,995,466.34 892.96 6,483.81 741.97 680,810.76 5,995,479.03 905.39 6,550.93 752.84 680,877.6 5,995,491.46 917.99 6,616.72 763.91 680,943.12 5,995,504.06 930.91 6,681.45 775.32 681,007.56 5,995,516.98 941.36 6,731.75 784.6 681,057.63 5,995,527.43 944.02 6,744.33 786.97 681,070.16 5,995,530.09 956.8 6,803.77 798.36 681,129.31 5,995,542.87 967.38 6,852.59 807.81 681,177.9 5,995,553.45 981.19 6,919.05 820.07 681,244.06 5,995,567.26 993.25 6,977.86 830.76 681,302.6 5,995,579.32 1,000.57 7,011.23 837.31 681,335.81 5,995,586.64 Page 4 WellGpma Pl-06 Pl-06 Pl-06 SuN Dpth Md 12,050. 12,092.33 12,183. Su~ D~hTvd 9,045.48 9,077.94 9,147.63 Azimuth 78.4 78.4 78.4 Incline 40.1 39.77 39.77 Radius 7,107.42 7,134.5 7,192.31 Map Dx 7,035.15 7,061.63 7,118.17 Map Dy 1,010.99 1,017.07 1,030.05 Surv Dx 7,056.81 7,083.43 7,140.25 SuN Dy 846.67 852.13 863.79 X Loc 681,381.16 681,407.64 681,464.18 YLoc 5,995,597.06 5,995,603.14 5,995,616.12 Page 5 Tape Subfile 2 is type: ..ZS TAPE HEADER PRUDHOE BAY UNIT rc / aD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 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 8 AK-MW- 60104 R. KRELL K. WHITE P1-06 500292269500 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 16-SEP-96 1453 710 42.38 40.88 8.60 OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 7.000 6035.0 6.000 4.500 12188.0 MWD - GR/EWR4. ALL DEPTHS ARE MEASURED BIT' DEPTHS. WELL P1-06 IS REPRESENTED BY RUNS 1, 3, 4, 5, 7, & 8. RUNS 1, 2, 4, 5, & 7 ARE DIRECTIONAL ONLY AND NO DATA IS PRESENTED. RUN 8 IS DIRECTIONAL WITH GAMMA RAY (DGR/SGRC) AND ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY (EWR4). GAMMA RAY DATA IS ACQUIRED WITH DUAL GAMMA RAY, GEIGER MUELLER TYPE DETECTORS AND IS NOTED AS DGR/SGRC. FILE H~ADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 11924.0 12160.0 RP 11931.0 12167.0 $ BASELINE CURVE FOR SHIFTS: GR (WALS, open hole, 26-Aug-96.) CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 11924.0 11929.5 11937.5 11944.5 11950.0 11964.5 12183.5 $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: GR 11929.0 11933.5 11944.5 11947.0 11952.0 11969.5 12188.5 BIT RUN NO MERGE TOP 8 12050.0 MERGE BASE 12188.0 MERGED MAIN PASS. CN WN FN COUN STAT /??SHIFT. OUT $ : ARCO ALASKA, INC. : P1-06 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI RPX MWD 68 1 OHMM RPS MWD 68 1 OHMM RPM MWD 68 1 OHMM RPD MWD 68 1 OFSMM API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 6 FET MWD 68 1 HR 7~ ROP MWD 68 1 FPHR * DATA RECORD (TYPE# 0) Total Data Records: 18 998 BYTES * ~ 90 180 01 4 90 810 01 28 Tape File Start Depth = 12189.000000 Tape File End Depth = 11924.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4249 datums Tape Subfile: 2 107 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape' Su~ofile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11929.0 EWR4 11935.0 $ 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: MAXIM UMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ STOP DEPTH 12165.0 12172.0 28-AUG-96 4.54 SLIM PHASE 4 5.03/DEP II2.17f MEMORY 12188.0 12050.0 12188.0 0 39.8 39.8 TOOL NUMBER P0502SP4 P0502SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.000 6035.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: N-DISP KCL 10.10 49.0 8.9 18500 4.6 .240 .119 .150 .400 65.0 137.5 65.0 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT ARCO ALASKA, INC. P1-06 POINT MCINTYRE NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 2 RPX MWD 68 1 3 RPS MWD 68 1 4 RPM MWD 68 1 5 RPD MWD 68 1 6 FET MWD 68 1 7 ROP MWD 68 1 API API API API Lo9 Crv Crv Size Length Typ Typ Cls Mod AAPI 4 OHMM 4 OHMM 4 OHMM 4 OHMM 4 HR 4 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 17 Tape File Start Depth = 12189.000000 Tape File End Depth = 11929.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units . = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 3 4169 datums 82 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 4 is type: LIS 96/ 9/16 01 **** REEL TRAILER **** 96/ 9/16 ~ 01 Tape Subfile: 4 2 records... M£nimum record length: 132 bytes Maximum record length: 132'bytes End of execution: Mon 16 SEP 96 2:48p Elapsed execution time = 0.72 seconds. SYSTEM RETURN CODE = 0 10/7/96 · ~,,,,"~'"~J ~ 1 ~ I .i1.~:.] ~ [:.] ~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10452 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27)] Floppy Well Job # Lo~l Description Date BL RF Sepia Disk P 1-06 PE~FORATI~iG RECORD 96091 6 I I ' P1-06 STATIC PRESSURE SURVEY 960917 I 1 P1-24 CBL 960926 I 1 P 1-24 BRIDGE PLUG RECORD 960927 I 1 P 1-24 PERFORATING RECORD 960927 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 0 I:::t I I__1-- I !~ CS S I:::: I~! L~ I I-- E~ S WELL LOG TRANSNHTTAL To: State of Alaska October 9, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - DS P1-06, AK-MW-60104 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS Pl-06: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22695-00 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22695-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia - _ OCT 10 i996 .~a~ ~ & Gas Cons. Commi~on Anc~e 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dm~ser Industries. Inc. Comnanv D I::! I I_1_ I IM I~ WELL LOG TRAnNSI~HTTAL To: State of Alaska October 9, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 ~MWD Formation Evaluation Logs - DS P 1-06 AK-MW-60104 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.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted magnetic tape with LIS listing. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9¢7) 563-3256 · Fax (907) 563-7252 MEMORANDUM TO: David Jo~,'~ Chairmaff~_,P~ THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: August 15, 1996 Blair Wondzell, P. i. Supervisor FROM- Bobby Foster~r'~.-~' SU BJ ECT: Petroleum Inspector FILE NO: G2GIHODD.DOC Surface Cement ARCO - PBU - Pt. Mc. 1-6 PTD # 96-0137 Prudhoe Bay Field Thrusday, August 15,1996: ! traveled this date to ARCO's Point Mc Intyre well 1-6 after receiving a call from Kirk White, SDS rep., informing me that they did not circulate cement to surface. I went to the rig and met with Kirk. He informed me that they had run7" casing to 6,038' MD (4,800"I-VD) and had pumped 70 bbls. of water spacer, 296 bbls. of Articset 3 and 37 bbls. Of class G cement at a rate of 6 to 10 bbls./min. Followed by drilling mud to displace the casing. They bumped the plug and had no flow back. He said good returns were received ali during the job but the casing could not be recipoited. Kirk wanted to know what to do next and i told him that the top of the cement would have to be located and how he did that was up to him and I departed the location. Kirk paged me in approximately an hour and said that they had run a 1" pipe in the hole and tagged cement at 73' below the surface and ask if ! would like to see it. I told him I certainly would and l went back to the rig. ! arrived in approximately 30 minutes and had the crew clean out the end of the 1" pipe which was cut off at about a 60 degree angle. They then ran the pipe back in the hole and tagged up again. I had the crew turn the pipe about a round and a half and pull it pack out of the hole. There was a good sample of cement in the end of the pipe which I put in a cup. ! talked to the mud engineer and we tested the sample with Ph paper and the Ph was about 14 which is good cement. I contacted Blair Wondzell and gave him ali the information and it was decided to let the rig do the top job and continue the operation. SUMMARY: I witnessed the tagging of the surface cement on ARCO's Point Mclntyre #1-6 at 73' and after speaking with my supervisior approved the cementing to surface operation. Attachments: NONE X Unclassified Classified Unclassified with Document Removed TONY KNOWLE$, GOVEFiNOR ALASKA OIL AND GAS CONSERYATION COMMISSION August 7, 1996 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279~1433 FAX: (907) 276-7542 Steve Shultz, Sr Drlg Engr ARCO Alaska inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Pt Mclntyre P1-06 ARCO Alaska, Inc. 96-137 1453'NSL, 710'WEL, Sec 16, T12N, R14E, UM 2335'NSL, 1156'EWL, Sec 14, T12N, R14E, UM Dear Mr Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. David V~. Johi Chairmar¥,,~ BY ORDER OF Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. OMMISSION dlf/enc c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o enct STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. 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 ARCO Alaska Inc. Plan RTE = 42.8' Point Mclntyre 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034624 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1453' NSL, 710' WEL, SEC. 16, T12N, R14E Point Mclntyre At top of productive interval 8. Well Number Number U-630610 2239' NSL, 679' EWL, SEC. 14, T12N, R14E P1-06 At total depth 9. Approximate spud date Amount $200,000.00 2335' NSL, 1156' EWL, SEC. 14, T12N, R14E 08/08/96 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028297, 1156'I P1-07 (08), 13.93' @ surface 2560 12139' MD / 9049' TVD 16. To be completed for deviated wells 117. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 300' Maximum Hole Angle 49° Maximum surface 3320 psig, At total depth (TVD) 8800' / 4200 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) 30" 20" 133# H-40 Weld 80' Surface Surface 80' 80' 260 sx Arcticset (Approx.) 8-1/2" 7" 29# L-80 NSCC 6004' 30' 30' 6023' 4943' 746sxCS III, 177sx'G',250sxCS II 6" 4-1/2" 12.6# 13CR80 NSCT 6266' 5873' 4843' 12139' 9049' 355 sx Silicalite 119. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner Perforation depth: measured '" :~, .... ~.':"~: true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Jim Smith, 564-5026 Prepared By Name/Number Kathy Campoamor, 564-5122 21. I hereby certify that t~s .~.~~to the best of my knowledgeSigned ,~,/3/,///~::~ SteveShu~ v Title Senior Drilling Engineer Date "'~Commission Use Only Permit Number I APl Number [ ~..App_ rovaJ,~ate ] See cover letter ~'~'"-//:~> '7' 50- Cz 9-- ';~'-~" ~ 7-~" ~'~'~ ~/~' for other requirements Cor~ditions'of ~pproval: Samples Required [] Yes~ No Mud Log Required [] Yes ~. No Hydrogen Sulfide Measures '~Y~s [] No Directional Survey Required ~ Yes [] No Required Working Pressure for BOPE [-]2M; []3M; ,~ 5M; [] 10M; [] 15M Other: Original Signed By by order of Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 II~IVIU VV, dUllltO }~ Submit In Triplicate I WellName: IP1-06 Well Plan Summary I Type of Well (producer or injector): I Producer Surface Location: 1453' FSL, 710' FEL, Sec. 16, T12N, R14E UM Target Location: 2239' FSL, 679' FWL, Sec. 14, T12N, R14E UM Bottom Hole Location: 2335' FSL, 1156'FWL, Sec. 14, T12N, R14E UM ling: I Doyon #14 ]OPerating days to complete: ] 17 AFE Number: ] 2C0097 ] Estimated Start Date: ] 8/8/96 MD: 1 12139' I ITv~: Well Design (conventional, slimhole, etc.): [ 9049' rkb I [KBE: 142.8 [ Monobore [Objective: [ Kuparuk Sand Formation Markers: Formation Tops MD TVD(BKB) Base Permafrost 1856 1853 SV4 4590 4003 Surface Casing 6023 4943 Surface casing point, 50' TVD above K-15 K- 15 6099 4993 Lower Ugnu 7771 6113 Need cement above Lower Ugnu West Sak 8679 6723 9.5 ppg minimum mud weight required K-10 11059 8323 'K-5 11327 8503 HRZ 11401 8553 Kalubik 11476 8603 Kupamk 11483 8608 10.1 ppg minimum mud weight required Miluveach 12075 9006 10.4 ppg may be required for Miluveach TD 12139 9049 Evaluation Program: SURFACE PRODUCTION CASED HOLE LOGS IMWD directional only MWD directional only with GR-RES-DEN-NEUT from TD to surface casing shoe None Well Plan Summary Page 1 Mud Program: Special design considerations An open hole displacement to +/- 10 ppg Flovis polymer/3% KC1 water based mud will be performed above the reservoir. Surface MudProperties: I$?UD DENSITY Marsh Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 8.7 300 40-60 30-60 60-80 9-10 15-25 9.6 150 30-40 20-30 40-60 9-10 < 15 Production Mud Properties: I LSND in upper hole DENSITY Plastic Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 9.4 8-15 20-30 5-15 <30 9-9.5 6-12 10.1 8-15 20-30 5-15 <30 9-9.5 6-12 Production Mud Properties: [ 3% KC1 in Kuparuk DENSITY Plastic Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 10.1 8-15 20-30 12-15 <30 9-9.5 4-6 HTHP <15 Directional'. [KOP: I 300' MD Maximum Hole Angle: Close Approach Well: 49° @ azimuth 89.5° at sfc csg point. Angle is tangent from 3560'MD to TD with 10© azimuth change to 78.8° PTMCINT-01, PTMCINT-02 and P1-07(08), P 1-05 shut in until surface casing is run. Casing/Tubing Program: Hole Size CSg] Wt/Ft' Grade Conn Length Top Btin Tbg O.D. MD/TVD MDfrVD 30" 20" 133# H-40 WLD 80' GL 80/80 8-1/2" 7" 29.0# L-80 NSCC 6004' 30'/30' 6023'/494Y · 6" 4-1/2" 12.6# 13Cr80 NSCT 6266' 5873'/4843' 12139'/9049' TBG 4-1/2" 12.6# 13CR80 NSCT 5843' 30'/30' 5873'/4843' Well Plan Summary Page 2 Cement Data: Casing/Liner 7" surface casing Shoe at 6023' 4-1/2" productiOn liner Shoe at 12139' Liner top at 5873' Lead: Sxs/Wt~ield 746/12.2/1.92 **250% excess lead in perma, 30% below to top of tail None Tail: Sxs/Wt/Yield 177/15.8/1.15 **30% excess tail & plan.750'TVD fillup which is 1143'MD 355/13.1/2:08 **30% excess with TOC at 150' above liner top Comments Cold Set III & Class "G Top of cement is 150' above the liner top Top Out Job (if necessary) 250/14.95/0.96 Top Out--CSll Drilling Hazards/Risks The original reservoir pressure is 4350 psi at 8800' TVDss. The expected reservoir pressure on this well is 4200 psi at 8800'TVDss. Abnormally pressured formations are not expected in this well. Tight hole has been experienced in the lower Sagavanirktok, near the surface casing shoe (4400'TVDss to 4800'TVDss). This has caused stuck pipe incidents and bit/BHA bailing Gumbo problems. ROP's in this section are typically very fast and care must be taken to ensure the hole does not become overloaded with cuttings. Sufficient pump rates must be achieved at all times to ensure the hole will be cleaned. Well Control:- Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system.schematics on file with AOGCC. Well Plan Summary Page 3 . o . , Se 7. 8. 9. 10. Pl-06 Operations Summary MIRU drilling rig. NU and function test diverter. Spud well and drill 8-1/2" hole to 300' md. Kick off and build angle to the north to clear offset wells, then mm to the east (89° azimuth) while continuing to build angle to the final tangent angle of 490 on 89.5° azimuth by 3560'MD. Hold angle to 602YMD which is surface hole TD (4943' TVD). Set 7", 29.0#, L-80,NSCC casing and cement same. Test casing to 3000 psi for 30 minutes. Nipple up BOP's and test same to 5000 psi. Note AOGCC witness or waiver on the morning report. P/U 6" BHA, drill 20' new hole and perform LOT. Drill ahead and drop angle from 49° to 47.8° while turning azimuth to 78.8© prior to 6535'MD. Continue with tangent below that point to TD at 12139'MD, 9049'TVD. Displace mud to 10 ppg 3% KC1 before top of Kuparuk. Run wireline open hole logs at TD. Make a cleanout run. POH and stand back drill pipe. Run 4-1/2" 12.6#, L-80, NSCT liner and cement same, displacing with seawater. Test liner to 3500 psi for 30 minutes. Run 4-1/2" tubing tieback and completion assemblY. ND BOP and NU tree assembly. Test tree assembly to 5000 psi. Displace tubing to diesel, freeze protect the annulus. Set packer, test tubing. Test annulus. Secure well, release rig. Well Plan Summary Page 4 BPX - Shaped Sepvlces lDmiLking ALaska PLane', Zone4 iVlec: P -06 As-Buik PI-06 WpP 7129196 3~45 pm 500 HF1RIZDNTAL VIEW (TRUE NORTH) SCALE 500 f't;, / DIVISIFIN SURVEY REP WELLHEAD ~'~ F'i,AN FEASIBILITY $']'UD~ ,r; i~ for feasibility puq31:l~l~ I:~1~11~ ' nas not yet been ~ifledl 000-- 500-- 500 -- ,000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 CRITICAL POINT DATA MD Inc Azi, TVD N/S E/W TIE IN 0 0,00 10,00 0 0 N 0 E KOP / START 300 O,OO 10,00 300 0 N 0 E DF BUILD ~ 1,00/100 ?t END OF BUILD 600 3,00 10,00 600 START OF 750 3,00 10,00 750 CURVE ~ 1,00/100 ?t END OF CURVE 1050 0,00 89,00 1050 START OF BUILD 1100 0,00 89,00 1100 ~ 1,00/100 Ct START OF BUILD 1400 3.00 89,00 1399 ~ 1,50/100 Ct END OF BUILD 1700 7,50 89.00 1698 Base 1856 7,50 89,00 1853 PermaFrost START OF 1900 7,50 89,00 1806 CURVE ~ 2,50/100 ?t END OF CURVE 3560 49,00 89,50 3327 SV4 3981 49,00 89,50 3603 UG4A(K-15) 6099 49,00 89,50 4993 START DF 6E10 49,00 89,50 5065 CURVE ~ E,50/100 Ct END OF CURVE 6535 47,76 78,76 5EBE U§nu 7771 47,76 78,76 6113 i Sak 8679 47,76 78,76 6723 K-lO 11059 47,76 78,76 8323 K-5 ~1327 47,76 78,76 8503 HRZ 1140~ 47,76 78,76 8553 Kalublk 11476 47,76 78,76 8603 T~et 11483 47,76 78,76 8608 (7/1-B/96) / Kuparuk ~luve~ch 12075 47,76 78.76 9006 8N ~5 N IE 3E 23N 4E 23N 4E 23 N 1P E P4 N 39 E 24 N 60 E P4 N 65 E 32 N 834 35 N 1152 49 N 2750 49 N 2834 74 N 3075 252 N 3973 383 N 4632 727 N 6360 766 N 6555 776 N 6609 787 N 6663 788 N 6668 874 N 7098 CASING POINT DATA OD MD Inc Azi TVD N/S E/W 7 in 6023 49,00 89,50 4943 48 N 2693 E 4 I/2 in 12139 47,76 78,76 9049 883 N 7145 E ITarRet N;me TVD NS EW Grid X Gr, id Y Target 1 (8123/96) 8608 916 N 6743 E 681065 5995660 Target (7/18/96) 8608 788 N 6668 E 680993 5995530 lID Depth(Pt) Toot Code P1-06 Wp2 0-12139 20.03 BPF~4-PBD PROPOSED BHL TVD 9049.02 MD 12139.36 VS 7198.92 N/S 882,93 N E/W 7144.57 E D~te PLotted Creoted By Checked By Approved By D~te 7129/95 SCALE 500 Ft, / DIVISION TVD-REF: WELLHEAD VERTICAL SECTION REF: WELLHEAD 0.00 ~ 0 MD TIE IN 2,D0 3,00 3,00 1,00 P,O0 3,00 300 MD KO° / START DF BUILD e 1,00/100 Ct 500 MD 600 MI) F_J~D OF BUILD 750 MD START DF CURVE ~ 1,00/100 ?'t 960 ND J~ ~ ~'E~-U~V~LD ~ I,DO/i00 ?t 1300 ND 1400 MD START DF BUILD e 1,50/100 Ft 6,00 ~ 1600 MD 7,50 ~ 17(]0 MD END OF B~LD F.~ ~ ti)E6 ~ ~',~?~~*~ 2.50/100 12,50 ~ 2100 MD 17,50 ~ 2300 MD 22,50 ~ 2500 ND 27.50 ~ 2700 ND 32,50 ~ 2900 HD 37.50 ~ 3100 MD 4250 ~ 3300 MD BPX - Sho, ned Se ices Dri. LLLr~.g, Alo, sko, S-i;o,-te Plo, ne: Zon,.e'4' "'x, Pt Mac', PHi i" i ': i i' .... 7.; ..... >:::::::' ' ............................. HAL~=~-~' Pi-06 As-BulL-t:; * , ;, , ',. ,' ..... ;L.._/ / \ // Pi-06 Est :.. ... .... 7129196 ~45 pm ID Depth(¢t) To~ Code P1-06 Wp2 0-i2i39 20.03 BPHH-PBD 832 1147 %g3nS~J~ON~[] END OF cURvE ,CE) ~ 3981 MD SV4 "' ~,N F~A~IBIUTY :~rUD~ . ,,..:: ~at V~t been ~Mifledl ~7 in UD, ~ &OR3 MD, 494~ TVD oFc v 3974 ~eZZZ1 MD L, U~u ~ 47,76 e 8679 MD W, ,76 e 11~9 MD K-lO -500 0 500 lO00 1500 2000 VERTICAL SECTION pLANE', 82,96 2500 3000 3500 4000 4500 5000 5500 60{)0 6500 7000 ru 7500 82 CRITICAL PBINT DATA MD Inc Azi. TVD TIE IN 0 0.00 10.00 0 KBP / START 300 0.00 lO,DO 300 BF BUILD 1.OD/lO0 ?t END DF BUILD 600 3,00 10,00 600 START DF 750 3,00 lO,O0 750 CURVE ~ 1,00/100 END DF CURVE 1050 0,00 89,00 i050 START OF B~JILD 1 lOO 0,00 89,00 1100 ~ 1,OD/lO0 START BF ]3U]LD 1400 3,00 89,00 1399 ~ 1,50/100 END DF BUILD 1700 7,50 89,00 1698 Base 1856 750 Bg,O0 1853 PenmaFnost START BF tgOO 7,50 89,00 CURVE ~ 2,50/100 ?t END DF CURVE 3560 49.00 89,5(] 3327 SV4 3981 49,00 89,50 3603 UG4A(K-15) 6099 49,DO 8950 4993 START OF 6210 49,00 Bg,50 5065 CURVE ~ 2,50/i00 ?t END DF CURVE 6535 47,76 78,76 5288 ~L Ugnu 7771 47,76 78,76 6113 : SaR 8679 47,76 78,76 6723 K- t 0 11059 47,76 78,76 8323 K-5 11327 47,76 78,76 8503 HRZ i i401 47.76 78,76 8553 KatuJ~ k 11476 47,76 78,76 8603 Tc~ ~e-t ! 1483 47,76 78,76 8603 (71EBIC)6) I Kup~uk Mituveach 12075 47,76 78,76 9006 N/S ~W ON OE ON OE 8N 1E 15N 32 23 N 4E 23 N 4E 23 N 12 E 24 N 39 E 24 N 60 E 24 N 65 E 32 35 49 49 74 252 383 727 766 776 787 788 874 N 834 E N li52 E N 2750 E N 2834 E N 3075 E N 3973 E N 4632 E N 6360 E N 6555 E N 66092 N 6663 E N 6668 E N 7098 E ITclr, Ret NoJ~ TVD NS EW Grid X Ct. id Y T~ge~ 1 (2/83/96) 8608 916 N 6743 E 681065 5995 Tomget 07/18/96) 8608 788 N 6668 E 680993 59951 CASING POINT DATA BI) MD ~c Azi TVD N/S E/W 7 in 6023 49.00 89.50 4943 48 N 2693 E 4 1/2 in i2i3g 47.76 78.76 g04g 883 N 7145 E Date PLotted Cne~ted By Checked 3y Approved By Date 7/29/96 Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.23.27 N - Long. 148.34.54 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (ft): 5994583.63 N 674346.08 E North Aligned To: TRUE NORTH Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD TVD Reference: WELLHEAD Halliburton Energy Services - Drilling Systems PSL Proposal Report Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2.2.2 Vertical Section Plane: 82.96 deg. Page 1 Proposal No: 96-026 Date: 7/29/96 Time: 3:43 pm Wellpath ID: P1-06 Wp2 Last Revision: 7/29/96 WELLPLAN FEASIBILITY STUDY This plan Is for feasibility purposes only it has not yet been certified~ BPX - Shared Services Drilling Alaska State Plane: Zone4 Pt Mac: PMI P1-06 As-Built P1-06 Wp2 Est Measured Incl Drift Subsea TVD Course Depth Dir. Depth Length (ft) (deg.) (deg.) (ft) (ft) (ft) TIE IN 0.00 0.00 0.00 -42.80 0.00 0.00 KOP / START OF BUILD @ 1.00 deg/100 ft 300.00 0.00 0.00 257.20 300.00 300.00 400.00 1.00 10.00 357.19 399.99 100.00 500.00 2.00 10.00 457.16 499.96 100.00 END OF BUILD 600.00 3.00 10.00 557.06 599.86 100.00 START OF CURVE @ 1.00 deg/100 ft 750.00 3.00 10.00 706.86 749.66 150.00 850.00 2.00 10.00 806.76 849.56 100.00 950.00 1.00 10.00 906.73 949.53 100.00 END OF CURVE 1050.00 0.00 0.00 1006.72 1049.52 100.00 START OF BUILD @ 1.00 deg/100fl 1100.00 0.00 0.00 1056.72 1099.52 50.00 1200.00 1.00 89.00 1156.72 1199.52 100.00 1300.00 2.00 89.00 1256.68 1299.48 100.00 START OF BUILD @ 1.50 deg/100fi 1400.00 3.00 89.00 1356.58 1399.38 100.00 1500.00 4.50 89.00 1456.37 1499.17 100.00 1600.00 6.00 89.00 1555.94 1598.74 100.00 END OF BUILD 1700.00 7.50 89.00 1655.25 1698.05 100.00 Base Permafrost 1856.09 7.50 89.00 1810.00 1852.80 156.09 START OF CURVE @ 2.50 deg/100 ft TOTAL Rectangular Offsets (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) 0.00N 0.00N 0.86N 3.44N 7.73N 15.46N 19.76N 22.34N 23.20N 0.00E 5994583.63 674346.08 0.00E 5994583.63 674346.08 0.15E 5994584.50 674346.21 0.61E 5994587.09 674346.61 1.36E 5994591.40 674347.26 2.73 E 5994599.16 674348.44 3.48E 5994603.47 674349.10 3.94E 5994606.06 674349.50 4.09E 5994606.92 674349.63 23.20N 23.21N 23.26N 4.09E 5994606.92 674349.63 4.96E 5994606.95 674350.50 7.58 E 5994607.06 674353.11 23.33N 23.45 N 23.61N 11.94E 5994607.24 674357.47 18.48E 5994607.51 674364.01 27.63 E 5994607.88 674373.15 23.81N 24.17N 39.38E 5994608.36 674384.89 59.75E 5994609.19 674405.25 Closure Vertical Build Walk DLS Cum. Dist. Dir. Section Rate Rate Dogleg (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) 0.0C@ 0.00 0.00 0.00 0.00 0.00 0.0 O.OC@ 0.00 0.00 0.00 0.00 0.00 0.0 0.87@ 10.00 0.26 1.00 0.00 1.00 1.0 3.45@ I0.00 1.02 1.00 0.00 1.00 2.0 7.85@ 10.00 2.30 1.00 0.00 1.00 3.0 15.7£@ 10.00 4.60 0.00 0.00 0.00 3.0 20.0~@ 10.00 5.88 -1.00 0.00 1.00 4.0 22.68@ 10.00 6.65 -1.00 0.00 1.00 5.0 23.55@ 10.00 6.90 -1.00 0.00 1.00 6.0 23.55@ 10.00 6.90 0.00 0.00 0.00 6.0 23.74@ 12.07 7.77 1.00 0.00 1.00 7.0 24.4~@ 18.05 10.38 1.00 0.00 1.00 8.0 26.21@ 27.10 14.71 1.00 0.00 1.00 9.0 29.8~@ 38.24 21.22 1.50 0.00 1.50 10.5 36.34@ 49.49 30.32 1.50 0.00 1.50 12.0 46.02@ 58.84 42.00 1.50 0.00 1.50 13.5 64.45@ 67.98 62.26 0.00 0.00 0.00 13.5 Expected Total Max Hor Min Hor Dir. Vert Rectangular Coords Error Error Max Err Error (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool O.OON 0.00 E 0.00 0.00 0.00 0.00N 0.00 E 2.00 2.00 0.00 0.86N 0.15 E 2.00 2.00 280.00 3.44N 0.61 E 2.01 2.00 280.00 7.73N 1.37 E 2.04 2.01 280.00 15.46N 2.74E 2.11 2.02 280.00 19.76N 3.49 E 2.15 2.02 280.00 22.34N 3.95 E 2.18 2.03 280.00 23.20N 4.10E 2.18 2.03 280.00 0.00 BPHM-PBD 0.39 BPHM-PBD 0.54 BPHM-PBD 0.69 BPHM-PBD 0.84 BPHM-PBD 1.06 BPHM-PBD 1.21 BPHM-PBD 1.36 BPHM-PBD 1.51 BPHM-PBD 23.20N 4.10E 2.18 2.03 280.00 23.21N 4.97E 2.19 2.04 284.10 23.25N 7.59 E 2.21 2.04 291.83 1.59 BPHM-PBD 1.74 BPHM-PBD 1.89 BPHM-PBD 23.31N 11.95 E 2.25 2.05 301.95 23.38N 18.49 E 2.33 2.07 313.74 23.48N 27.64 E 2.49 2.09 324.47 2.03 BPHM-PBD 2.18 BPHM-PBD 2.33 BPHM-PBD 23.58N 39.39 E 2.74 2.12 332.90 23.77N 59.77 E 3.23 2.19 340.36 2.48 BPHM-PBD 2.72 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Pag~ 2 Date: 7129196 Wellpath ID: P1-06 Wp2 Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool 1900.00 7.50 89.00 1853.54 1896.34 43.91 24.27N 65.48E 5994609.42 674410.97 69.83@ 69.66 67.96 0.00 0.00 2000.00 I0.00 89.14 1952.37 1995.17 100.00 24.51N 80.69E 5994610.02 674426.17 84.33@ 73.10 83.09 2.50 0.14 2100.00 12.50 89.23 2050.44 2093.24 I00.00 24.79N 100.20 E 5994610.75 674445.66 103.22@ 76.10 102.48 2.50 0.09 0.00 13.5 23.82N 65.50E 3.39 2.21 341.78 2.78 BPHM-PBD 2.50 16.0 23.88N 80.71E 3.89 2.29 345.13 2.93 BPHM-PBD 2.50 18.5 23.87N 100.22E 4.57 2.39 347.96 3.08 BPHM-PBD 2200.00 15.00 89.29 2147.56 2190.36 100.00 25.09N 123.96E 5994611.61 674469.41 126.48@ 78.56 126.10 2.50 0.06 2300.00 17.50 89.33 2243.56 2286.36 100.00 25.43N 151.94E 5994612.60 674497.37 154.05@ 80.50 153.91 2.50 0.04 2400.00 20.00 89.36 2338.25 2381.05 100.00 25.80N 184.08E 5994613.72 674529.49 185.88@ 82.02 185.85 2.50 0.03 2.50 21.0 23.77N 123.99E 5.44 2.54 350.25 3.23 BPHM-PBD 2.50 23.5 23.56N 151.98E 6.53 2.73 352.05 3.38 BPHM-PBD 2.50 26.0 23.21N 184.12E 7.82 2.96 353.47 3.54 BPHM-PBD 2500.00 22.50 89.39 2431.44 2474.24 100.00 26.19N 220.32E 5994614.96 674565.71 221.87@ 83.22 221.87 2.50 0.02 2600.00 25.00 89.41 2522.96 2565.76 100.00 26.62N 260.59E 5994616.33 674605.96 261.94@ 84.17 261.88 2.50 0.02 2700.00 27.50 89.42 2612.64 2655.44 100.00 27.07N 304.81E 5994617.81 674650.15 306.01@ 84.92 305.83 2.50 0.02 2.50 28.5 22.71N 220.37E 9.34 3.24 354.58 3.70 BPHM-PBD 2.50 31.0 22.04N 260.65E 11.08 3.56 355.45 3.87 BPHM-PBD 2.50 33.5 21.19N 304.89E 13.07 3.92 356.14 4.05 BPHM-PBD 2800.00 30.00 89.44 2700.31 2743.11 I00.00 27.55N 352.90E 5994619.41 674698.22 353.97@ 85.54 353.61 2.50 0.01 2900.00 32.50 89.45 2785.79 2828.59 100.00 28.06N 404.77E 5994621.13 674750.06 405.74@ 86.03 405.16 2.50 0.01 3000.00 35.00 89.46 2868.94 2911.74 100.00 28.59N 460.32E 5994622.96 674805.58 461.21@ 86.45 460.35 2.50 0.01 3100.00 37.50 89.47 2949.57 2992.37 100.00 29.14N 519.44E 5994624.89 674864.67 520.2~@ 86.79 519.10 2.50 0.01 3200.00 40.00 89.48 3027.56 3070.36 100.00 29.72N 582.03 E 5994626.94 674927.22 582.79@ 87.08 581.28 2.50 0.01 3300.00 42.50 89.48 3102.73 3145.53 100.00 30.32N 647.95E 5994629.08 674993.11 648.6~@ 87.32 646.78 2.50 0.01 3400.00 45.00 89.49 3174.97 3217.77 100.00 30.93N 717.10E 5994631.31 675062.21 717.7~@ 87.53 715.48 2.50 0.01 3500.00 47.50 89.50 3244.11 3286.91 100.00 31.57N 789.32E 5994633.64 675134.40 789.9~@ 87.71 787.24 2.50 0.01 END OF CURVE 3560.01 49.00 89.50 3284.07 3326.87 60.01 31.97N 834.09E 5994635.08 675179.14 834.71@ 87.81 831.72 2.50 0.01 SV4 3980.60 49.00 89.50 3560.00 3602.80 420.58 34.74N 1151.50E 5994645.30 675496.38 1152.02@ 88.27 1147.07 0.00 0.00 CASING POINT OD = 7 in, ID = 6.28 in, Weight = 26.00 lb/ft. 6023.10 49.00 89.50 4900.00 4942.80 2042.50 48.19N 2692.94E 5994695.08 677036.96 2693.37@ 88.97 2678.51 0.00 0.00 UG4A(K-15) 6099.31 49.00 89.50 4950.00 4992.80 76.21 48.69N 2750.45E 5994696.94 677094.45 2750.8~@ 88.99 2735.66 0.00 0.00 2.50 36.0 20.15N 352.99E 15.30 4.32 356.70 4.25 BPHM-PBD 2.50 38.5 18.89N 404.88E 17.79 4.75 357.14 4.47 BPHM-PBD 2.50 41.0 17.41N 460.45E 20.53 5.20 357.50 4.72 BPHM-PBD 2.50 43.5 15.70N 519.59E 23.55 5.67 357.79 5.00 BPHM-PBD 2.50 46.0 13.75N 582.20E 26.83 6.16 358.03 5.32 BPHM-PBD 2.50 48.5 11.56N 648.15E 30.39 6.66 358.23 5.68 BPHM-PBD 2.50 51.0 9.13N 717.32E 34.22 7.17 358.39 6.08 BPHM-PBD 2.50 53.5 6.45N 789.58E 38.32 7.68 358.53 6.52 BPHM-PBD 2.50 55.0 4.75N 834.37E 40.89 7.98 358.60 6.81 BPHM-PBD 0.00 55.0 7.11S 1151.90E 58.99 10.15 358.91 8.97 BPHM-PBD 0.00 55.0 48.19N 2692.94E 0.00 0.00 0.00 0.00 BPHM-PBD 0.00 55.0 66.87 S 2751.50E 151.11 21.28 359.29 21.19 BPHM-PBD START OF CURVE @ 2.50 deg/100 ft 6210.01 49.00 89.50 5022.63 5065.43 110.70 49.42N 2834.00E 5994699.65 677177.95 2834.43@ 89.00 2818.66 0.00 0.00 6310.01 48.51 86.24 5088.56 5131.36 100.00 52.20N 2909.12E 5994704.22 677252.98 2909.5~@ 88.97 2893.56 -0.49 -3.26 6410.01 48.12 82.93 5155.08 5197.88 100.00 59.24N 2983.45 E 5994713.02 677327.11 2984.04@ 88.86 2968.19 -0.39 -3.31 0.00 55.0 69.99 S 2835.08 E 155.93 21.87 359.30 21.85 BPHM-PBD 2.50 57.5 70.62S 2910.42E 160.23 22.40 359.21 22.44 BPHM-PBD 2.50 60.0 66.92S 2985.16E 164.45 22.93 359.05 23.02 BPHM-PBD 6510.01 47.82 79.59 5222.04 5264.84 100.00 70.52N 3056.84E 5994726.03 677400.22 3057.6{@ 88.68 3042.42 -0.30 -3.34 END OF CURVE 6534.82 47.76 78.76 5238.71 5281.51 24.81 73.97N 3074.89E 5994729.91 677418.18 3075.78@ 88.62 3060.75 -0.24 -3.36 L. Ugnu 7771.45 47.76 78.76 6070.00 6112.80 1236.63 252.47N 3972.86E 5994929.70 678311.62 3980.87@ 86.36 3973.83 -0.00 0.00 2.50 62.5 58.89 S 3059.16E 168.58 23.45 358.82 23.59 BPHM-PBD 2.50 63.1 56.23 S 3077.36E 169.60 23.58 358.76 23.73 BPHM-PBD 0.00 63.1 82.43N 3983.24E 220.66 30.08 356.42 30.87 BPHM-PBD W. Sak 8678.88 47.76 78.76 6680.00 6722.80 907.43 383.44N 4631.78 E 5995076.38 678967.21 4647.63@ 85.27 4643.84 -0.00 0.00 K-10 11059.04 47.76 78.76 8280.00 8322.80 2380.15 727.00N 6360.11E 5995461.38 680686.72 6401.52@ 83.48 6401.25 -0.00 0.00 K-5 11326.80 47.76 78.76 8460.00 8502.80 267.77 765.65N 6554.54E 5995504.72 680880.16 6599.11@ 83.34 6598.96 0.00 0.00 0.00 63.1 184.18N 4647.98 E 258.28 34.87 355.30 36.13 BPHM-PBD 0.00 63.1 451.07N 6391.54E 357.27 47.48 353.48 49.95 BPHM-PBD 0.00 63.1 481.09N 6587.69E 368.42 48.91 353.34 51.50 BPHM-PBD HRZ 11401.18 47.76 78.76 8510.00 8552.80 74.38 776.38N 6608.55E 5995516.76 680933.90 6654.0£@ 83.30 6653.88 Kalubik 0.00 0.00 0.00 63.1 489.43N 6642.18E 371.52 49.30 353.30 51.94 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Pag~ 3 Date: 7/29/96 Wellpath ID: P1-06 Wp2 Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool 11475.56 47.76 78.76 8560.00 8602.80 74.38 787.12N 6662.56E 5995528.80 680987.63 6708.9£@ 83.26 6708.80 0.00 0.00 Target (7/18/96) / Kuparuk 11483.00 47.76 78.76 8565.00 8607.80 7.44 788.19N 6667.96E 5995530.00 680993.00 6714.3~@ 83.26 6714.29 -0.00 -0.00 12039.36 47.76 78.76 8939.00 8981.80 556.36 868.50N 7071.96E 5995620.07 681394.92 7125.0~@ 83.00 7125.09 0.00 0.00 0.00 63.1 497.77N 6696.67E 374.61 49.70 353.26 52.37 BPHM-PBD 0.00 63.1 498.61N 6702.11E 374.92 49.73 353.26 52.41 BPHM-PBD 0.00 63.1 560.99N 7109.67E 398.10 52.69 353.00 55.65 BPHM-PBD Miluveach 12075.06 47.76 78.76 8963.00 9005.80 35.70 873.65N 7097.88E 5995625.85 681420.71 7151.45@ 82.98 7151.45 0.00 0.00 CASING POINT OD = 4 1/2 in, ID = 3.95 in, Weight = 12.60 lb/ft. 12139.30 47.76 78.76 9006.18 9048.98 64.24 882.92N 7144.53 E 5995636.25 681467.12 7198.88@ 82.96 7198.88 0.00 0.00 12139.36 47.76 78.76 9006.22 9049.02 0.06 882.93N 7144.57E 5995636.26 681467.16 7198.92@ 82.96 7198.92 0.00 0.00 0.00 63.1 565.00N 7135.83E 399.59 52.88 352.98 55.85 BPHM-PBD 0.00 63.1 882.92N 7144.53 E 0.00 0.00 0.00 0.00 BPHM-PBD 0.00 63.1 572.21N 7182.93E 402.27 53.22 352.95 56.23 BPHM-PBD WELLPLAN FEASIBILITY STUDY This plan is for feasibility purposes only it has not yet been certifiedJ FIELD & POOL 666 WELL PERMIT CHECKLIST , , , COMPANY~?~c· ~ ADMINISTRATION WELLNAME/~./~d-~~ , PROG :expa de redri~a servE] wellbomseg I-lann. disposal para req UNIT# ON/OFF SHORE F 1. Permit fee attached ....................... IV N 2. Lease number appropriate ................... tyY N 3. Unique well name and number ................ N 4. Well located in a defined pool ................. Y N 5. Well located proper distance from drlg unit boundary ..... ¥ N 6. Well located proper distance from other wells ......... ¥ 7. Sufficient acreage available in drilling unit. .......... ¥ 8. if deviated, is wellbore plat included .............. Y 9. Operator only affected party .................. ¥ 10. Operator has appropriate bond in force .......... ~ . ¥ 11. Permit can be issued without conservation order ..... ¥ ,/~ ~/~. 12. Permit can be issued wilhout administrative appmval .... ¥ . 13. Can permit be approved before 15-day wait. ......... ¥ ENGINEERING Conductor string provided .................. N Surface casing protects all known USDWs ......... CMT vol adequate to circulate on conductor & surf csg . . . CMT vol adequate to tie-in long string to surf csg ...... N CMT will cover all known productive horizons ......... N Casing designs adequate for C, T, B & permafrost. ..... N Adequate tankage or reserve pit. ............... N abndnmnt been ~ If a re-drill, has a 10-403 for approved... Adequate wellbore separation i N proposed ........... If diverter required, is it adequate ................ N Drilling fluid program schematic & equip list adequate .... BOPEs adequate ............. :,--'x,.,'~ ...... ~ N BOPE press rating adequate; test to :~.~c~ ~ psig.~),N Choke manifold complies w/APl RP-53 (May 84) ....... Work will occur without operation shutdown ......... N Is presence of H2S gas probable ............... N GEOLAREA/ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. REMARKS GEOLOGY ,/ 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N// ~ 31. Data presented on potential overpressure zones ....... ,Y,/~r,, /'(, ~/,~ /~, 32. Seismic analysis of shallow gas zones ............. _~..N. 33. Seabed condition survey ('[~ off-shore) ........... //. Y N 34. Contact name/phone for weekly progress repoT ,..../.. Y N lexpk~ramryon~y.! /' GEOLOGY: ENGINEERING: COMMISSION: BEW~ ~.~ ~/5'//~ DWJ JDH ~ JDN _. .,.~..~::~._ TAB Comments/InsU'uctions: HOW/lib - AN:OR~ist rev 4~g6
