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202-245
David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 05/03/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU S-109 PTD: 202-245 API: 50-029-23135-00-00 ULTRA SONIC IMAGING TOOL (USIT) CEMENT EVALUATION 01/15/2003 Please include current contact information if different from above. 202-245 T38767 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.13 11:12:14 -08'00' Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. 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 have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 S-109 202245 500292313500 7 9/19/2023 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1°K1CIt.0r_IVr.0 IdN In 9019 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate p Pull Tubing ❑ OperationstOGICIG Suspend ❑ Perforate 13Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development m Exploratory ❑ 5. Permit to Drill Number: 202.245 3. Address: P.O. Box 196812 Anchorege, AK 99519-6612 Stratigrephic ❑ Service ❑ 6. API Number: 50-029-23135-00.00 7. Property Designation (Lease Number): ADL 028257 e. Well Name and Number: PBU S-109 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, AURORA OIL 11, Present Well Condition Summary. Total Depth: measured 11600 feet Plugs measured None feet true vertical 6794 feet Junk measured None feet Effective Depth: measured 11600 feet Packer measured 7552 feet true vertical 6794 feet Packer true vertical 6624 feet Casing. Length: Size: MD: TVD: Buret Collapse: structural Conductor 80 20" 29-109 29-109 1490 470 Surface 3002 9-5/8" 29-3031 29-2849 5750 3090 Intermediate 7794 7" 26-7820 26-6741 7240 5410 Scab Liner 3726 2-7/8" 7719-11145 6699-6829 10570 11160 Liner 3824 4-1/2" 7646-11470 6666-6818 8430 7500 Perforation Depth: Measured depth: 7898-11428 feet True vertical depth: 6768-6824 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 24-7653 24-6669 Packers and SSSV (type, measured and 4-1/2" Baker Premier Packer 7554 6624 true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): See Attached Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In Subsequent to operation: No Test Available 14. Attachments: frequred ver 20 MC 25,mo2s071. & 2255.2831 15. Well Class after work: Daily Report of Well Operations &I( Exploratory El Development ® Service ❑ Stratigrephic ❑ ry\� 16. Well Status after work: Oil 0 • Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ " ry\ Printed and Electronic Fracture Stimulation Data IZ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-272 Authorized Name: Lastufka, Joseph N Contact Name: Shriver, Tyson Authorized Title: Speci 'stI Contact Email: TysoaShriverabp,cam Authorized Signature: Data: I,'O!' Contact Phone: +1 9075644133 RBDMS JAN 1 12019 Original Only 3 Form 10404 Revised 04/2017 Submit C-jW 3/26/Lcx q OZ of 1 / 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-109 Acid Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-245 50-029-23135-00-00 11600 Conductor Surface Intermediate Liner Liner 6794 80 3001 7794 3824 3726 11438 20" 9-5/8" 7" 4-1/2" 2-7/8" 6793 30 - 110 29 - 3031 26 - 7820 7646 - 11470 7719 - 11445 30 - 110 29 - 2849 26 - 6741 6666 - 6818 6699 - 6822 None 470 3090 5410 7500 11160 None 1490 5750 7240 8430 10570 7898 - 11428 4-1/2" 12.6# L-80 24 - 7653 6768 - 6824 Structural 4-1/2" Baker Premier Packer 7552, 6624 7552 6624 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, AURORA OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028257 24 - 6669 2-7/8" Liner from 7700 - 11438'MD Pump 105-bbls 12% HCL acid. Final pressure =1250-psi. 277 677 555 325 546 2382 1716 1550 225 300 N/A 13b. Pools active after work:AURORA OIL No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 11:36 am, Jan 24, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.01.24 06:17:49 -09'00' Torin Roschinger (4662) WCB 2024-06-25 RBDMS JSB 013024 DSR-1/26/24 ACTIVITY DATE SUMMARY 1/8/2024 CTU#1 1.5" CT. Job Scope: Acid Stim Rig up CTU. Perform Weekly BOP Test. Perform Well Control, Man Down and H2S drills. Finish rig up and PT WHE, RIH w/ slim BHA 1.5" JSN. Dry tag at 9,525' ***Job continued on 9-Jan-2024*** 1/9/2024 ***Job Continued from 8-Jan-2024*** Tagged high @ 9525'. Jetted through bridge and able to inject 1bpm @ ~1500psi. Continue dry drift, tag once more @ 11350' but able to work passed w/o pumping. Tag TD @ 11462'. Confirm tag and PUH to 10' off bottom and flag pipe. Begin pump schedule circulating 40 bbls Diesel, 85 bbls KCL w/F103. Once 2 bbls 12% HCl exited nozzle. Close choke. Reciprocate across liner (up/down/up) jetting 12% HCl across Liner. Injectivty= 0.5 bpm at ~ 1035psi. Pump Acid at 0.5bpm to get more contact time to clean potential Liner scale.. Pump a total of 105 bbls 12% HCl. Swap to KCL + 2gpt F103. Perform down/up/down/up passes jetting Acid out of Liner. Final Injectivity = 0.7bpm @ 1030psi. 1bpm @ ~ 1035psi. 1.7 bpm @ 1160psi. 2.3 bpm @ ~ 1250psi. 2.8 bpm @ ~ 1375psi. Freeze Protect Coil w/ Diesel. Freeze Protect Tbg w/ 40 bbls diesel (2500' tvd). Acid load out had the wrong amount of scale inhibitor RBIH and make 2 passes across liner pumping 100bbls KCLw/L066(8bbls) followed by 1 pass pumping 50bbls 1% KCL flush. POOH. ***Job Continued on 10-Jan-2024*** 1/10/2024 CTU #1 1.5" Coil, Job Objective: Acid Stim ***Continued from 9-Jan-2024*** Finish POOH. RDMO CTU. ***Job Complete / Well Testers up next for Acid Flowback*** 1/14/2024 ****WELL S/I ON ARRIVAL**** (Perforating) RAN 3.80" GAUGE RING TO 7,419' SLM (unable to work past) RAN 3.78" SWAGE & 2.50" SAMPLE BAILER TO 7,423' SLM (unable to work past, tools stick, bailer empty) RAN 4-1/2" BRUSH & 3.50" GAUGE RING TO 7,423' SLM (unable to work past) RAN 3-1/2" BRUSH & 2.70" GAUGE RING TO DEPLOYMENT SLEEVE AT 7,719' MD (-4 correction) ***CONTINUE ON 1/15/24 WSR*** 1/15/2024 ***CONTINUED FROM 1/14/24 WSR*** (Perforating) RAN SBHPS w/ STOPS PER PROGRAM ***WELL LEFT S/I ON DEPARTURE*** Daily Report of Well Operations PBU S-109 g Begin pump g@ g gg schedule circulating 40 bbls Diesel, 85 bbls KCL w/F103. Once 2 bbls 12% HCl g exited nozzle. Close choke. Reciprocate across liner (up/down/up) jetting 12% HCl()jg across Liner. Injectivty= 0.5 bpm at ~ 1035psi. Pump Acid at 0.5bpm to get more jy g contact time to clean potential Liner scale.. Pump a total of 105 bbls 12% HCl. Swap to KCL + 2gpt F103. Perform down/up/down/up passes jetting Acid out of Liner Acid load out had the wrong amount ofg()g scale inhibitor RBIH and make 2 passes across liner pumping 100bblsg KCLw/L066(8bbls) followed by 1 pass pumping 50bbls 1% KCL flush. POOH T/1/0=0/0/70 SI Assist SLB Frac crew (FRACTURING) Pumped 2 bbls DSL down IA to maintain/hold IAP @ 2500-2600 psi while SLB performs FRAC. Blead IA to 1900 psi. SLB 12/16/2018 incontrol of well upon departure See log for details. Job Scope: Fracture Treatment - Stages #1, 2, & 3 of 5 Data Frac and 2000 lbs 100 mesh scouring stage. ISIP 1860 psi. (.7 gradient) Stage #1 100,000 lbs sand 1- 7 ppa. Avg treating pressure 5050 psi @ 16.5 bpm. Drop ball and open frac port #2 Stage #2 109,000 lbs sand 1- 8 ppa. Avg treating pressure 5160 psi @ 16 bpm. Drop ball and open frac port #3 Stage #3 Screenout with 8 ppa and half of the 7 ppa stage behind pipe. Pumped 98,000 lbs with -60,000 lbs behind pipe. Avg treating pressure 5050 psi @ 18 bpm. f Total of 309,000 lbs sand and 275,000 lbs behind pipe ;eav h L /t yL 2- Proppant 16/20 Carbolite and each zone topped of w/ 16/20 Carbo -Bond Squeezed 1.5 bbl diesel freeze protect into well. Partial RD for CT FCO. 12/16/2018 ****Frac will resume after CT FCO**** CTU#8 1.5" CT Job Scope: FCO MIRU CTU. Perform BOP Test. 12/17/2018 ***Continued on 12/18/18*** CTU#8 1.5" CT Job Scope: FCO MU & Rih Slim w/ 1.50" BDJSN. Tag sand at 414'. Reverse circulate down to 1Q _with 100% returns. Limiting no more than - 10% solids in Coil. Increase ROP in 2-7/8" Liner. 12/18/2018 ***In Progress*** CTU#8 1.5" CT. Job Scope: FCO MU & Rih Slim w/ 1.50" BDJSN. Tag sand at 414'. Reverse circulate down to TOL with 100% returns. Limiting no more than - 10% solids in Coil. Increase ROP in 2-7/8" Liner. Tag Frac Sleeve #4. Unable to get thru. Perform and Injectivity test: 0.5 bpm at 2500 psi. MU 1.78" DJN & Rih. 12/18/2018 ***Continued on 12/19/18*** LRS 76 heat frac tanks to 110*. Heated frac tanks #8, 9, 10, 12, 13 to 110* F. RDMO. SLB 12/18/2018 notified of tanks status. CTU#8 1.5" CT. Job Scope: FCO Resume RIH w/ 1.78" DJN. Tagged at 9532'. Pressure up the backside. Shift open Frac Sleeve #4. Pooh. Freeze Protect well w/ 60/40 meoh. RDMOL. 12/19/2018 ***Job Complete*** Job Scope: Resume Frac - Treat Stages #4 and #5 Stage 4 - 100,000 lbs 16/20 Carbolite / Carbo bond, Avg treating pressure 4400 psi @ 25 bpm. Drop ball and open frac port #5 Stage 5 - Screened out. Pumped 80,000 lbs sand -60,000 lbs in formation) Avg treating pressure 5050 psi @ 22 bpm. Displaced w/ 12 bbls crosslinked gel. Only .25 bbls diesel away before pumps tripped out Too of sand displaced to 780'(1.935" OD dissolvable ball on top of sand). 20,000 lbs. of 16/20 carbo -bond (36 bbls equivalant) remain in wellbore. Settled depth of sand - -5800'. Only the tree is freeze protected. 12/19/2018 ***Job Complete*** T/1/0=frac/258/51 ***Assist SLB Frac crew *** (FRACTURING) Heat load 90 bbls Diesel for SLB transport at 90*. Pumped 1.3 bbls of diesel into IA to pressure up IA to 2400 psi initially. Pumped an additional .17 bbl dsl during frac to maintain 2500 to 2600 psi. Bled IA numerous times to maintain 2500 to 2600 psi. FWHP= frac/1650/121 **Fluid packed tags hung on IAV,WV** 12/19/2018 **AFE sign in place on arrival** Schlumberger FracCAT Treatment Report: S-109 Stages 1-3 Wel S-109 Field Aurora Formation Kuparuk C Well Location : County : Prudhoe Bay State :Alaska Country United States Prepared for 2888.6 Client BP Exploration Alaska Client Rep ArvelI Bass & Tyson Shriver Date Prepared December 16, 2018 Prepared by Name Alexander Martinez Division Schlumberger Phone 561 389 5006 Pressure (All Zones) Initial Wellhead Pressure (psi) 568 Surface Shut in Pressure(psi)777 4,800 Calibration Surface ISIP (psi) 2236 Final Surface ISIP (psi) NIA Maximum Treating Pressure (psi) TotalsTreatment Total Slurry Pumped (Water+Adds+Proppant) (bola) 5,673 3405.5 Total YF128FIexD Past Wellhead (bbls) 2888.6 Total WF128 Past Wellhead (bbls) 185.7 Total FP past WH (bbls) 2 Total Proppant Pumped (Ibs.) 308,969 Total Proppant in Formation (Ibs.) 275,045 Total 100 Mesh Sand Pumped (Ibs) 13,414 Total 16/20 Carbolite Pumped (Ibs) 176,754 Total 16/20 Carbo8ond Pumped (Ibs) Total Chemical Additives Invoiced F103 (gal) 129 118,801 Past VVH 129 Invoiced M275 (lbs.) 44 Fast VJH 40 L065 (gal) 129 129 J475 (Ibs.) 1018 1018 L071 (gal) 260 260 J134(Ibs.) 20 0 J604 (gal) 313 313 M002 (Ibs.) 147 147 J580 (Ibs.) 3840 3558 5123 (gal) 84 84 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well orwells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges mayvary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Schlumberger -Private Schlumberger Job Plots: Pressure Test — Tr. Press — Annulus Press — Slurry Rate Client: BP Alaska Well: S-109 Formation: Kuparuk Distrito: Prudhoe Bay, AK Country: United States BP Exploration Alaska S-109 16 -Dec -2018 O Schlumberger 19942016 Time - hh:mm:ss Schlumberger -Private 34 Schlumberger 14 7 12 6 10 5 N 8 3 4 v n 9) j 6 v 3 3 D S O Schlumberger 19942016 Time - hh:mm:ss Schlumberger -Private 34 Schlumberger Schlumberger a F- DataFrac — Tr. Press — Annulus Press — Slurry Rate Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country United States BP Exploration Alaska S-109 16 -Dec -2018 0 ® Schlumberger 19942016 Time - hh:mm:ss Schlumberger -Private v Q 3 Schlumberger V Schlumbener 5000 4000 N N m 3000 CL 2000 1000 Stages 1-3 Client: BP Alaska Well. S-109 Formation. Kuparuk District Prudhoe Bay, AK Country. United States — Tr. Press BP Exploration Alaska — Annulus Press S-109 16 -Dec -2018 — Slurry Rate — Prop Con 25 r16 0= 14:26:23 C Schlumberger 1990-2016 152443 16:23:03 1721:23 Time - hh:mm:ss Schlumberger -Private 20 12 0 10 15 ` 0 00 m 8 � Q � 10 3 D 6 4 5 0 18:19:43 Schlumberger Schlumberger E Stage 1 Client: BP Alaska Well: S 109 Formation: Kuparuk District: Prudhoe Bay. AK Country: United States — Tr. Press 13P Exploration Alaska — Annulus Press S-109 16 -Dec -2018 — Slurry Rate — Prop Con 16 14 12 Time - hh:noon :ss Q 3 © Schlumberger 1994-2016 Schlumberger Schlumberger -Private Schlumberger Stage 2 Client: BP Alaska Well: S 109 formation: Kuparuk District: Prudhoe Bay, AK Country: United States — Tr. Press l Exploration Alaska — Annulus Press S-109 16 -Dec -2018 — Slurry Rate — Prop Con 20 r16 ® Schlumberger 19962016 Time - hh:mm:ss Schlumberger -Private 0 510 Schlumberger 14 15 12 N 10 E � O g C� 10 N 9 8 0� Q Q � � 3 D 6 5 4 0 510 Schlumberger Schlumberger N d Stage 3 Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country. United States Tr Press BP Exploration Alaska Annulus Press S-109 16 -Dec -2018 Slurry Rate Proo Con 16 O Schlumberger 1991 Time - hh:mm:ss Schlumberger -Private 0 V 0 0 Schlumberger Schlumberger 20 15 5 0 13:13:43 Data Frac: Additives — SLUR—RATE CFLD_RATE J604_CONC Gina rnmr Client: BP Alaska Well: 5-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States SP Exploration Alaska S-109 16 -Dec -2018 © Schlumberger 1994-2016 10 20 — L071_CONC — U028_CONC — S123_CONC — J475_CONC 19 9 18 17 8 © Schlumberger 1994-2016 10 20 19 9 18 17 8 16 15 7 14 N c 13m 6 D 12 `a a 11 5 10 O 9 O 4 °— 8 Q m 7 m _ m 3 6 5 2 4 3 1 2 1 0 13:22:03 1330:23 133843 13:47:03 Time - hh:mm:ss Schlumberger -Private Schlumberger Schlumberger 20 15 3 0 14:18:16 Stages 1-2: Additives SLUR–RATE CFLD RATE J604_CONC F103 CONC Client: BP Alaska Well: S-109 Formation: Kupamk District: Prudhoe Bay, AK Country: United States SP Exploration Alaska S-109 16 -Dec -2018 09 Schlumberger 1990-2016 14:59:56 15:41:36 Time - hh:mm:ss Schlumberger -Private 10 9 8 7 r n 6 a o. 5 a 3 m m 3 2 1 0 16:23:16 17:04:56 Schlumberger PD A cn O z n a 3 m v — L071_CONC — U028 CONIC I� — S123 CONIC J475_CONC r 09 Schlumberger 1990-2016 14:59:56 15:41:36 Time - hh:mm:ss Schlumberger -Private 10 9 8 7 r n 6 a o. 5 a 3 m m 3 2 1 0 16:23:16 17:04:56 Schlumberger PD A cn O z n a 3 m v Schlumberger 25 20 5 C 17:02:25 Stage 3: Additives — SLUR—RATE CFLD_RATE — J604_CONG — F103 CONIC Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States BP Exploration Alaska S-109 16 -Dec -2018 © Schlumberger 1994-2016 17:19:05 17:35:45 Time - hh:mmss Schlumberger -Private 17:52:25 10 — L071_C6NC 20 9 — U028_CONC 18 8 — S123_CONC 16 7 — J475 CONC 14 N n c m 6 D 12 t V n © Schlumberger 1994-2016 17:19:05 17:35:45 Time - hh:mmss Schlumberger -Private 17:52:25 10 20 9 18 8 16 7 14 N n c m 6 D 12 t V n n <n 5 10 O N Z O m 4 ° 8 v ,p m 3 m 3 6 2 4 1 2 -0 0 Schlumberger Scmumberger Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States Section 1: Stage 1: As Measured Pump Schedule Schlumberger -Private Stage Pressures & Rates As Measured Pump Step # , Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Minimum Treating Pressure Pressure (psi) (psi) 1 Slurry Slurry Pump 2262 Fluid 556 Max Prop Prop Step Step 74 Calibration 10.0 10.0 Pup 5203 02 # Name Volume Rate Time Fluid Name Volume Proppant Name Cal Cont Conc Mass A38 5269 (bbl) (bbVmin) (min) 15.4 (gal) 148 PPA) (PPA) (lb) 1 Brevando 21. 4.1 5. WF128 91 Scour 0 0 0 5245 045 Res Pad 15.3 15.5 204 5260 148 10 1.0 PPA 2 Breyarkdo 25 8.2 3.6 WF128 1043 15.5 0 0 0 044 12 3.0 PPA 16.4 16.6 5129 5210 043 13 .0 PPA 17.2 3 Calibrati 42. 1 4.3 YF128FIexD 178 117.7 0 0 0 15 on 17.4 17.6 5114 181 062 16 .0 PPA 17.3 17.4 4 0.5 PPA 10 1 9.2 YF128FlexD 430 100 Mesh Sand 1.1 0. 212 5 Cal Cont 11. 18. 0. YF128FlexD 489 0. 6 Displace 13 15. 9.5 WF128 584 ment 7 PAD 100 15. 6.8 YF128FIexD 419 0.1 8 Scour 150 16. 9.1 YF128FlexD 616 100 Mesh Sand 1. 0. 3072 9 Res Pad 50. 15. 3.3 YF128FlexD 213 0. 0 10 1.0 PPA 100.2 15. 6.5 YF128FIexD 403 CarboLite 16/20 1.2 1 398 11 2.0 PPA 100.1 15. 6.5 YF128FIexD 387 CarboLite 16/20 2.1 2 756 12 3.0 PPA 99.6 16. 6.1 YF128FIexD 370 CarboLite 16/20 3.1 1091 13 4.0 PPA 10 17. 5. YF128FlexD 358 CarboLite 16/20 4.2 4 1414 14 5.0 PPA 10 17. 5. YF128FIexD 345 CarboLite 16/20 5.1 4. 1707 15 6.0 PPA 84. 17. 4. YF128FIexD 283 CarboLite 16/20 6. 5. 1679 16 .0 PP 76. 17. 4. YF128FIexD 251 CarboBond Lite 16/20 6.1 6 15142 17 7.0 PPA 60. 16. 3. YF128FIexD 203 CarboBond Lite 16/20 7.1 5. 1094 18 Clear 18 16. 1.1 YF128FlexD 768 -0.1 0 Lines 19 Ball 1 16. 0.1 YF128FIexD Al.0 Schlumberger -Private Stage Pressures & Rates Step # Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Minimum Treating Pressure Pressure (psi) (psi) 1 Breakdown 4.1 4.6 2262 2527 556 2 Breakdown 8.3 10.0 W62 74 Calibration 10.0 10.0 i156 5203 02 .5 PPA 12.0 18.5 1898 5162 t279 Cal Cont 18.5 18.9 A38 5269 t954 Displacement 15.4 17.6 148 5438 1217 PAD 15.8 18.2 915 5215 925 8 Scour 16.6 18.1 188 5245 045 Res Pad 15.3 15.5 204 5260 148 10 1.0 PPA 15.3 15.7 171 5214 124 11 2.0 PPA 15.5 16.2 135 5247 044 12 3.0 PPA 16.4 16.6 5129 5210 043 13 .0 PPA 17.2 17.5 109 P253 036 14 .0 PPA 117.5 117.7 125 184 3311 15 .0 PPA 17.4 17.6 5114 181 062 16 .0 PPA 17.3 17.4 5140 244 091 17 .0 PPA 1fi.8 17.1 5142 211 053 1992 18 Clear Lines t6.6 16.9 5087 167 Schlumberger -Private Scmumberiger Client: BP Alaska Well: S-189 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step / Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 19 Ball 16.9 16.9 74 76 071 Average Treating Pressure: 5044 psi Maximum Treating Pressure: 5438 psi Average Injection Rate: 15.5 bbl/min Maximum Injection Rate: 18.9 bbl/min Average Horsepower: 1931.7 hhp Maximum Horsepower: 2433.0 hhp Maximum Prop Concentration: 7.1 PPA Section 2: Stage 1: Job Messages Schlumberger -Private Message Log 8 Time Message Treating Pressure (psi( Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min( Prop. Conc. (PPA) 1 Reset Executed Steps 01 01 0. 2 Reset Executed Steps 01 01 0. 3 Reset Executed Steps 01 01 0. 4 Reset Executed Steps OS 01 0. 5 Reset Executed Steps 1. 01 01. 0. 6 Reset Executed Steps 0. 0. 0. 7 Reset Executed Steps 0. 0. 0. 8 Reset Executed Steps 0. 0. 0. 9 Reset Executed Steps 0. 0. 0. 10 Reset Executed Steps 0. 0. 0. 11 9:23:39 Lines are fluid packed 0. 0. 0. 12 9:24:53 Priming pumps 0 0. 0. 0. 13 9:49:08 Pumps are primed 0. 0. 0. 14 10:05:54 Low PT looks good 111 1 0. 0. 0. 15 10:06:21 Coming up to 4K for check valve test 1986 1 0. 0. 0. 16 10:11:33 Check valve test is good 2953 1 0. 0.1 0. 17 10:12:24 Coming up for high PT 2925 1 0. 0.1 0. 18 10:19:33 Found leak on manifold 6724 1 01 OJ 0. 19 10:20:29 Bleed pressure off 12 1 0. 0. 0. 20 10:48:17 PT is good 7085 1 OJ 0. 0. 21 10:49:05 Bleeding off pressure to have safety meeting 7058 1 01 0. 0. 22 11:12:56 IMixing 288 gel 131 lol CA 0. 0. 23 12:48:20 Priming up pod with gel 23 0.0, 0. 0. 24 13:00:38 Opening the well 238 0. 01 0. 25 13:01:03 Start Breakdown Automatically 55 2381 0. 0. 0. 26 13:01:03 tart Propped Frac Automatically 55 2381 0. 0. 0. 27 13:01:03 Start Stage 1; For Automatically 55 2381 0. 0.4 0. Schlumberger -Private Schlumberger Client: 8P Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States Schlumberger -Private Message Log # Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 28 13:01:08 3tarted Pumping 556 2381 0.0 0.0 0. 29 13:03:18 Nctivated Extend Stage 2326 2530 7.0 4.2 0. 30 13:13:05 fisplayed diesel ID49 2228 21.7 0.0 0. 31 13:14:43 Deactivated Extend Stage 992 2224 21.7 0.0 0. 32 13:14:54 3tart Breakdown Manually 987 2223.21.7 0.0.0. 33 13:19:06 Start Calibration Automatically 5051 257 46.0 10.0 0. 34 13:20:12 Activated Extend Stage 5169 256 57.8 9.9 0. 35 13:23:21 Deactivated Extend Stage 5146 259 89.1 9.9 0. 36 13:23:21 Start 0.5 PPA Manually 5146 259 89.1 9.9 0. 37 13:23:21 Started Pumping Prop 5146 259 89.1 9.9 0. 38 13:23:45 Activated Extend Stage 5152 2601 93.1 10.0 0. 39 13:29:35 Stage at Perfs: Breakdown 4427 2551 151.2 10.0 0. 40 13:31:20 Stage at Perfs: Breakdown 48031 2617 173.0.16.1 1. 41 13:32:31 Deactivated Extend Stage 4899 2603 193.N 18.5 0.1 42 13:32:32 Start Cal Cont Automatically 4954 2596 194.1 18.3 0.1 43 13:32:45 Stage at Perfs: Breakdown 5197 2621 198.1 18.9 -0. 44 13:33:10 Start Displacement Manually 5160 2626 205. 16.9 0. 45 13:33:16 Stopped Pumping Prop 5161 2637 207. 17.4 0. 46 13:33:28 Activated Extend Stage 5178 2621 211.1 17.4 0. 47 13:35:25 Stage at Perfs: Calibration 5055 2574.240.1 14.5 0. 48 14:32:47 Deactivated Extend Stage 1638.2201 344.1 1.0 0. 49 14:33:05 Start PAD Automatically 352 238A 344.q 4.4 0. 50 14:33:07 Stage at Perfs: 0.5 PPA 38 24371 344.q 4.4 0. 51 14:34:35 Stage at Perfs: Cal Cont 435N 2470 356. 12.0 0. 52 14:39:45 Started Pumping Prop 51 255 443. 18.1 0. 53 14:39:51 Start Scour Automatically 516 255 444. 18.1 0.1 54 14:42:44 Stage at Perfs: Displacement 50471 261 496.1 17.8 0. 55 14:48:56 tart Res Pad Automatically 523 258 595. 15.5 0. 56 14:49:00 tage at Perfs: PAD 524 258 596.1 15.5 0. 57 14:49:14 topped Pumping Prop 524 258 599. 15.5 0.1 58 14:52:08 tatted Pumping Prop 515 259 643.9 15.2 0. 59 14:52:11 ctivated Extend Stage 515 259 644.7 15.2 0. 60 14:52:14 Deactivated Extend Stage 514 259 645.4 15.2 0. 61 14:52:15 tart 1.0 PPA Automatically 513 259 645.7 15.2 0. 62 14:58:47 Start 2.0 PPA Automatically 5217 256 746.q 15.6.1. 63 14:58:48 Stage at Perfs: Scour 519 259 746. 15.7 1. 64 15:02:06 Stage at Perfs: Res Pad 514 260 796. 15. 2. 65 15:05:15 art 3.0 PPA Automatically 509 258 846. 16.1 2. 66 15:08:23 Stage at Perfs: 1.0 PPA 5187 254 897. 76.2 3. 67 15:11:20 Start 4.0 PPA Automatically 502 252 945.7 16.6 3. 68 15:14:21 Stage at Perfs: 2.0 PPA 51 253 997. 17.4 4. 69 15:17:09 Start 5.0 PPA Automatically -2891 -115 1045. 17.4 4. 70 15:20:05 Stage at Perfs: 3.0 PPA 51 252 1096. 17.7 4. 71 15:22:52 Start 6.0 PPA Automatically 51 2571 1145. 17.4 5. 72 15:25:48 Stage at Perfs: 4.0 PPA 5159 2577 1196. 17.6 5. 73 15:26:58 ctivated Extend Stage 5117 257 1217. 17.1 5. 74 15:27:44 Deactivated Extend Stage 5136 257 1230. 17.3 6.1 75 15:27:45 tart 6.0 PPA Automatically 514 257 1230. 17.3 6.1 76 1 15:31:35 Ptage at Perfs: 5.0 PPA 5212 2580 1296.0 17.3 6.1 Schlumberger -Private Schlumberger Client: OP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country. United States Schlumberger -Private Message Log d Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 77 15:32:12 tart 7.0 PPA Automatically 5208 256 13oT4 17.1 5. 78 15:33:09 Activated Extend Stage 5181 2571 1323.5 16.9 Ti 79 15:35:47 Deactivated Extend Stage 5134 256 1367.5 16.9 -0.1 80 15:35:47 Start Clear Lines Manually 5134 256 1367.5 16.9 -0.1 81 15:36:37 Stage at Perfs:6.0 PPA 4993 253 1381.6 16.5 -0.1 82 75:36:52 Start Ball Manually 5081 25411 1385.71 16.9 -0.1 Schlumberger -Private Scmumberger Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States Section 3: Stage 2: As Measured Pump Schedule Average Treating Pressure: Stage Pressures & Rates Minimum Treating Pressure: As Measured Pump Average Slurry Rate (bbl/min) , Average Treating Pressure (psi) Maximum Treating Minimum Treating Pressure Pressure (psi) (psi) 1 PAD to st be Step # Step Ste Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Prop p PPA) Prop Conic (PPA) Prop Mass (lb) 1 PAD 152.1 14.6 10.6 YF128FlexD 6400 241 187 0 0 0 2 Scour 200 14.8 13.6 YF128FlexD 8214 100 Mesh Sand 0.7 0.5 4124 3 PAD 22 14 1.6 YF128FlexD 925 18.8 0.5 0 0 4 1.0 PPA 81.1 13.8 5.9 YF128FIexD 3263 CarboLite 16/20 1.1 1 3243 5 12.0 PPAI 871 13.91 6.21 YF128FlexD 3365 CarboLite 16/20 2.11 21 6564 6 3.0 PPA 79.2 16. 4.7 YF128FlexD 2946 CarboLite 16/20 3.1 2. 8639 7 4.0 PPA 79.9 18. 4.4 YF128FIexD 2861 CarboLite 16/20 4.2 3. 11290 8 5.0 PPA 79.2 18. 4.2 YF128FIexD 2737 CarboLite 16/20 5. 4. 13474 9 6.0 PPA 84.1 18. 4.5 YF128FIexD 2805 CarboLite 16/206.1 5. 16579 10 7.0 PPA 100.7 18. 5.4 YF128FIexD 3207 Carbol3ond Lite 16/20 7. 6. 22012 11 8.0 PPA 116.1 17. 6.5 YF128FIexD 3784 CarboBond Lite 16/20 8.4 6.1 2372 12 Ball 1 17.4 0.1 YF128FIexD 42 01 01 Average Treating Pressure: Stage Pressures & Rates Minimum Treating Pressure: Step # Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Minimum Treating Pressure Pressure (psi) (psi) 1 PAD to st be 14.6 16.9 949 244 850 Cour 14.8 75.5 168 227 108 PAD 14.0 14.0 5217 225 206 7.0 PPA 13.8 14.1 207 241 187 .0 PPA 13.9 15.6 096 247 968 .0 PPA 16.9 17.5 102 214 984 .0 PPA 18.4 19.3 093 207 33 .0 PPA 18.9 19.2 143 210 96 .0 PPA 18.8 19.0 5155 206 16 10 .0 PPA 18.6 18.9 170 214 21 113 11 .0 PPA 17.9 18.3 171 313 28 12 Ball 17.4 17.4 5313 313 Average Treating Pressure: 5123 psi Maximum Treating Pressure: 5313 psi Minimum Treating Pressure: 3850 psi Average Injection Rate: 16.3 bbl/min Maximum Injection Rate: 19.3 bbl/min Average Horsepower: 2050.2 hhp Maximum Horsepower: 2444.4 hhp Maximum Prop Concentration: 8.9 PPA Schlumberger -Private Scmumberger Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States Section 4: Stage 2: Propped Frac: Job Messages Schlumberger -Private Message ,1 # Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Bate (bbUmin) Prop. Cone. (PPA) 1 15:36:56 tart PAD to st be Automatically 509 254 0. 16.9 -0. 2 15:36:56 Start Propped Frac Automatically 5098 2545 0.1 16.9 -0. 3 15:36:56 Start Stage 2; Por Automatically 5098 2545 IDA 16.9 -0. 4 15:41:25 Stage at Perfs:6.0 PPA 5251 2597 71A 14.9 -0. 5 15:45:58 IStage at Perfs: Clear Lines 4601 2556 131. 11.9 -0. 6 15:46:34 jActivated Extend Stage 4929 2600 138.7 13.4 -0. 7 15:47:22 tage at Perfs: Ball 5057 261 149. 14.2 -0.1 8 15:47:27 tage at Perfs: PAD to st be 5188 262 151. 14.5 0. 9 15:47:30 Deactivated Extend Stage 52 263 151.7 14. 0. 10 15:47:31 tart Scour Automatically 5198 262 152. 14. 0. 11 15:57:20 tage at Perfs: Scour 5209 2597 299. 14.5 0. 12 16:01:05 tart PAD Automatically 5206 259 352. 14.0 0. 13 16:01:26 Activated Extend Stage 5213 258 356. 14.0 -0. 14 16:02:38 Deactivated Extend Stage 5225 259 373. 14.0 0. 15 16:02:39 Start 1.0 PPA Automatically 5222 2 374. 14.0 0. 16 16:06:04 Activated Extend Stage 5207 258 421.1 13.7 1. 17 16:08:31 Deactivated Extend Stage 5242.257 454. 13.7 1. 18 16:08:32 tart 2.0 PPA Automatically 525 257 455.1 13.1 1. 19 16:11:47 tage at Perfs: PAD 513 25 499. 13.5 2. 20 16:13:23 tage at Perfs: 1.0 PPA 498 252 521. 14.2 2. 21 16:14:47 Start 3.0 PPA Automatically 5134 2531 542.2 15.6 1. 22 16:18:22 tage at Perfs: 2.0 PPA 510 251A 602.3 17.0 3. 23 16:19:29 tart 4.0 PPA Automatically 510 2500 621.6 17.5 3. 24 16:23:12 tage at Perfs: 3.0 PPA 5211 261 689.6 18.8 4. 25 16:23:50 tart 5.0 PPA Automatically 512 259N 701.4 18.6 4. 26 16:27:24 tage at Perfs: 4.0 PPA 520 258 768. 19.1 5. 27 16:26:01 Start 6.0PPA Automatically 515 25811 780. 18.8 5. 28 16:31:39 tage at Perfs: 5.0 PPA 519 2541 848. 19.0 5. 29 16:32:01 ctivated Extend Stage 519 2531 855.7 18.8 6. 30 16:32:28 Deactivated Extend Stage 5174 2521 864. 18.7 5. 31 16:32:29 Start 7.0PPA Automatically 5184 251 864. 18.7 5. 32 16:35:52 Stage at Perfs: 6.0 PPA 51 25 927. 18.7 6. 33 16:37:54 Start 8.0PPA Automatically 51 259 965. 18.3 6. 34 16:38:05 ctivated Extend Stage 514 258 968. 18.3 7. 35 16:40:27 Stage at Perfs: 7.0 PPA 5186 254 1011. 18.1 8. 36 16:44:23 Deactivated Extend Stage 5316 251 1081. 17.3 -0. 37 16:44:23 Start Ball Manually531 251 1081. 17.3 -0. Schlumberger -Private Schlumhepgep Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States Section 5: Stage 3: As Measured Pump Schedule Average Treating Pressure: Stage Pressures & Rates Average Injection Rate: As Measured Pump Step # Step Name , Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Minimum Treating Pressure Pressure (psi) (psi) Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gall Proppant Name Drax IPPA) Prop Conic (PPA) Prop Mass (lb) 1 PAD 161 13.9 12.8 YF128FIexD 6768 1.0 PPA 0 0 0 2 Scour 200 14.7 14.1 YF128FIexD 821 C 100 Mesh Sand 0.7 0.5 4088 3 PAD 20 16.3 1.2 YF128FIexD 840 128 0.5 0 0 4 1.0 PPA 50 16.2 3.1 YF128FIexD 2020 Carbol-ite 16/20 1.1 0.9 1831 5 12.0 PPAIII 5 16.21 3.11 YF128FIexD 1937 Carbol-ite 16/20 2.1 1.91 3709 6 3.0 PPA 5 16.4 3 YF128FIexD 1862 Carbol-ite 16/20 3.1 2. 5412 7 4.0 PPA 5 18. 2.7 YF128FIexD 1793 Carbol-ite 16/20 4.23. 6975 8 5.0 PPA 5 19. 2.5 YF128FIexD 1730 Carbol-ite 16/20 5.1 4. 8450 9 6.0 PPA 101. 2 5.1 YF128FIexD 3385 Carbol-ite 16/20 6.1 5.91 20101 10 7.0 PPA 10 20.1 5 YF128FIexD 3178 Carbol3ond Lite 16/20 7.1 6.q 22041 11 8.0 PPA 101. 18. 9 YF128FIexD 3144 CarboBond Lite 16/20 23.9 7.q 24944 12 F PP7 2. O.A 2.8 Freeze Protect 0 OT0 Average Treating Pressure: Stage Pressures & Rates Average Injection Rate: 16.9 bbl/min Step # Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Minimum Treating Pressure Pressure (psi) (psi) i PAD to st be 13.9 17.3 994 313 19 Scour 14.7 17.1 084 229 5 PAD 16.3 16.3 132 161 109 1.0 PPA 16.2 16.3 D50 5166 5128 .0 PPA 16.2 76.4 153 174 P105 .0 PPA 16.5 17.4 073 177 860 .0 PPA 18.7 19.6 977 128 829 .0 PPA 19.9 0.1 985 175 1797 903 .0 PPA 20.0 0.1 801 941 717 10 .0 PPA 20.1 0.1 929 004 814 11 .0 PPA 18.7 0.2 976 673 1 12 Clear Lines 18.7 1U.0 1976 19 Average Treating Pressure: 5006 psi Maximum Treating Pressure: 5673 psi Average Injection Rate: 16.9 bbl/min Maximum Injection Rate: 20.2 bbl/min Average Horsepower: 2080.6 hhp Maximum Horsepower: 2529.9 hhp Maximum Prop Concentration: 23.9 PPA Schlumberger -Private Schlumberger Section 6: Stage 3: Job Messages Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States Schlumberger -Private Message Log # Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbVmin) Prop. Cone. (PPA) 1 16:44:27 Start PAD to st be Automatically 5045 2473 01 16.7 0. 2 16:44:27 Start Propped Frac Automatically 5045 2473 01 16.7 0. 3 16:44:27 Start Stage 3; Por Automatically 5045 2473 OS 16.7 0. 4 16:44:56 Activated Extend Stage 5135 2483 81 16.8 -0.1 5 16:45:53 Stopped Pumping Prop 515 2561 24. 16.5 -0. 6 16:46:15 Stage at Perfs: 8.0 PPA 5198 2561 30.0 16.5 0. 7 17:06:07 Stage at Perfs: PAD to st be 513 2 746. 6. 0. 8 17:06:18 Stage At Perfs 52 2637 147. 6. 0. 9 17:08:03 tarted Pumping Prop 5090 259 160.6 8.6 0. 10 17:08:04 Deactivated Extend Stage 5107 260 160. 8.7 0. 11 17:08:05 tart Scour Automatically 5092 260 160. 9.1 0. 12 17:18:49 tage At Perfs 5118 260 304.4 16.7 0. 13 17:22:14 Start PAD Automatically 5112 261 361.1 16.3 0. 14 17:23:27 Start 1.0 PPA Automatically 5155 263 360.9 16.4 -0. 15 17:26:32 Start 2.0 PPA Automatically 5166 262 430.9 16.2 1. 16 17:29:38 Start 3.0 PPA Automatically 5097 256 461.1 16.2 2. 17 17:31:03 Stage at Perfs: 1.0 PPA 5126 258 504.3 16.4 3. 18 17:32:15 Stage at Perfs: 2.0 PPA 4892.257 524.2 17.0 3. 19 17:32:39 Start4.OPPA Automatically 488 2577 531.1 17.6 2. 20 17:34:58 Stage at Perfs: 3.0 PPA 5117 262 574. 19.3 3. 21 17:35:19 Start 5.0 PPA Automatically 515 262 581.1 19.7 4. 22 17:37:30 tage at Perfs: 4.0 PPA 492 259 624. 20.0 4. 23 17:37:49 tort 6.0 PPA Automatically 49 259 631, 20.1 5. 24 17:39:59 tage at Perfs: 5.0 PPA 4801 2547 674.3 20.0 5. 25 17:42:29 tage at Perfs: 6.0 PPA 47 248 724. 20.1 6. 26 17:42:30 Activated Extend Stage 4778 248 724. 20.1 6. 27 17:42:52 Deactivated Extend Stage 4877 249 732.1 20.1 6. 28 17:42:53 Start 7.0 PPA Automatically 4850 248 732. 20.1 6. 29 17:44:58 Stage at Perfs: 7.0 PPA 4873 251 774. 20.1 6. 30 17:47:52 Start 8.0 PPA Automatically 4980 255 832. 20.1 7.1 31 17:48:06 Activated Extend Stage 4946. 255 837. 20.1 7. 32 17:50:01 Stage at Perfs: 8.0 PPA 5D69 252 875.7 20.1 7. 33 17:58:49 Screened out 4974 251A 932.N 0.0 3. 34 17:59:13 Shutting in the well 4978 2510 932.N 0.0 3. 35 18:08:51 Bleeding the pressure off the lines 106 248 932. o.q 3. 36 18:09:50 Stopped Pumping Prop 65 2481 932. 0. 3.1 37 18:10:16 Beginning to clean surface line 0 0. 0.1 E. 38 18:11:07 Deactivated Extend Stage 311 247 932. 6.1 0. 39 18:35:49 Getting lined up to pump diesel into the well 77 243 932. 0. 0. 40 18:37:37 Matching wellhead 72 243 932. 0. 0. 41 18:38:42 Started Pumping 4856 243 932. CA 0. 42 18:38:45 Activated Extend Stage 4850 243 932. 0. 0. 43 19:05:05 Started Pumping 54 191 932. 1.1 0. 44 19:13:34 rying to pump diesel into the well 479 238 934. 0. 0. 45 19:13:36 Deactivated Extend Stage 419 236 934. 0. 0. 46 19:13:36 Start Clear Lines Manually 479 238 934. 0. 0. 47 19:13:39 Activated Extend Stage 479 238 934. 0. 0. Schlumberger -Private Scmumberger Client: BP Alaska Well: S-109 Formation: Kupamk District: Prudhoe Bay, AK Country: United States Message Log Message # Time Treating Pressure (psi) Annulus Total Slurry Slurry Bate Pressure (psi) (bbl) (bbl/min) Prop. Conc. (PPA) 48 19:19:59 Well is closed 4882 238 934. 0. 0. 49 19:21:44 Bleeding the pressure 58 236 934. 0. 0. Sch lu mberger-Private Schiumbepger, FracCAT Treatment Report: S-109 Stages 4-5 Well S-109 Field Aurora Formation Kuparuk C (stage 4) Kuparuk A (stage 5) Well Location 5656 2213.1 County Prudhoe Bay State :Alaska Country United States Prepared for 0.5 Client BP Exploration Alaska Client Rep Arvell Bass & Tyson Shriver Date Prepared December 19, 2018 Prepared by Name Alexander Martinez Division Schlumberger Phone 5613695006 Pressure (All Zones) Initial Wellhead Pressure (psi) 740 Surface Shut in Pressure(psi) 4800 Maximum Treating Pressure (psi) Treatment Totals (All Zones As Per FracCAT) Total Slurry bbls Pumped (Water+Adds+Proppant) 5656 2213.1 Final Surface ISIP (psi) Total YF128FIexD Past Wellhead (bbls) NIA 1845.2 Total WF128 Past Wellhead (bbls) 183.1 Total FP past WH (bbls) 0.5 Total Proppant Pumped (lbs.) 189,851 Total Proppant in Formation (lbs.) 159,533 Total 100 Mesh Sand Pumped (lbs) 7386 Total 16/20 Carbolite Pumped (Ibs) 85066 Total 16120 CarboBond Pumped (Ibs) Total Chemical Additives Invoiced 97399 Past VVH Invoiced FastWH F103 (gal) 82 82 M275 (lbs.) 28 23 L065 (gal) 85 85 J475 (Ibs.) 660 660 L071 (gal) 158 158 J134 (Ibs.) 20 0 J604 (gal) 249 249 M002 (lbs.) 100 100 J580 (Ibs.) 2781 2781 S123 (gal) 56 56 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notifythe owner or owners of the well orwells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges mayvary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Schlumberger -Private Schlumberger Job Plots: Pressure Test ouu 700 600 500 N Q N � 400 a` 3000 2000 1000 0 Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States — Tr. Press BP Exploration Alaska — Annulus Press S-109 19 -Dec -2018 — Slurry Rate — Prop Con 7 r10 v — BH Prop Con .--Found Drip 0 0 0 0 4�-'� 11:31:42 11:42:07 11:52:32 12:02:57 Time - hh:mm:ss © Schlumberger 1994-2016 Schlumberger -Private a 8 5 7 T 6 v 4 0 d i7 m 5 O 3 Cr Q 3 4 D 2 3 2 1 0 12:1322 Schlumh®rger 11:31:42 11:42:07 11:52:32 12:02:57 Time - hh:mm:ss © Schlumberger 1994-2016 Schlumberger -Private a 8 5 7 T 6 v 4 0 d i7 m 5 O 3 Cr Q 3 4 D 2 3 2 1 0 12:1322 Schlumh®rger 0 12:1322 Schlumh®rger Schlumberger y d N 4) o_ F Stage 4&5 Overview — Tr. Press — Annulus Press — Slurry Rate — ProD Con Client: BP Alaska well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States BP Exploration Alaska S-109 19 -Dec -2018 © Schlumberger 7994-2018 Time - hh:mm:ss Schlumberger -Private Ln 10 c -a � O a Ib n If B O Q � v 6 D 4 2 0 Schlumberger, Schlumhergep I� a Stage 4 Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States Tr. Press SP Exploration Alaska Annulus Press S-109 19 -Dec -2018 Slurry Rate Proo Con © Schlumberger 1996-2016 Time - hh:mm:ss Schlumberger -Private 16 Schlumberger Schlumberger a Stage 5 — Tr. Press — Annulus Press — Slurry Rate — Prop Con Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States BP Exploration Alaska S-109 19 -Dec -2018 ® Schlumberger 1994-2016 Time - hh:mm:ss Schlumberger -Private 16 14 Schlumberger Schlumbugep End of Job — Tr Press — Annulus Press — Slurry Rate — Prop Con Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States BP Exploration Alaska S-109 19 -Dec -2018 © Schlumberger 1994-2016 Time - hh:mm:ss Sc h I u m berger-Private Schlumberger 0 a Q 0 D Schlumberger 30 25 P 5 0 13:00:54 Stages 4&5: Additives — SLUR—RATE — CFLD_RATE — J604_CONC — F103 CONC Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States BP Exploration Alaska S-109 19 -Dec -2018 Q Schlumberger 1994-2018 10 0 25 — L671_CONC 8 — U028_CONC 20 7 r — S123_CONC n a — J475_CONC 'V Y i Il a iJ Q Schlumberger 1994-2018 10 0 25 9 8 20 7 r n a a 6 15 `a D a v 5 m C N 2 r 4 ° 10 a o d � 3 2 5 1 0 133824 14:15:54 14:53:24 153054 Time - hh:mm:ss Schlumberger -Private Schlumberger Scmumbepger Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country United States Section 1: Stage 4: As Measured Pump Schedule Step # Step Name Stage Pressures & Average Slurry Maximum Slurry Rate Rate (bbl/min) (bbl/min) Rates Average Treating Pressure (psi) Maximum Treating Minimum Treating Pressure Pressure (psi) (psi) As Measured Pump Schedule .4 12.5 319 014 Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Ball 17.3 6.4 5.4 WF128 134 0.0 835 840 831 2 attempt 157.5 14.3 11.2 WF128 6615 0 0 0 3 PAD 55.2 18.7 2.8 YF128FIexD 2318 294 0 0 0 4 1 Scour 11 20 201 101 YF128FIexD 82141 100 Mesh Sand 0.71 0.51 524 5 PAD 2 201 1 YF128FlexD 83 381 0 0 0 6 1.0 PPA 120 24.11 5 YF128FlexD 48361 CarboLite 16/20 1.1 1 474 7 2.0 PPA 119.6 2N 4.8 YF128FIexD 46291 CarboLite 16/20 2.1 2 929 8 3.0 PPA 119.9 251 4.8 YF128FIexD 4461 CarboLite 16/20 3.1 3 13527 9 4.0 PPA 125.1 2 5 YF128FIexD 447 CarboLite 16/20 4.2 1825 10 5.0 PPA 3. 25. 0.1 YF128FIexD 12 CarboBond Lite 16/20 3. 48 11 5.0 PPA 120.7 25. 4.8 YF12BFIexD 412 CarboBond Lite 16/20 5.2 21754 12 6.0 PPA 121.4 25 4.9 YF128FIexD 3998 CarboBond Lite 16/20 6.4 5.9 25251 13 7.0 PPA 76. 24. 3.21 YF128FIexD 2581 CarboBond Lite 16/20 7.51 5.q 1526 14 Clear Lines 2 19 2 1 YF128FIexD 82 CarboBond Lite 16/20 0. 0. 15 Ball 1 20 YF128FIexD 41 CarboBond Lite 16/20 1 0.41 0.1 0 Step # Step Name Stage Pressures & Average Slurry Maximum Slurry Rate Rate (bbl/min) (bbl/min) Rates Average Treating Pressure (psi) Maximum Treating Minimum Treating Pressure Pressure (psi) (psi) 1 Ball .4 12.5 319 014 40 PAD to st be 16.6 0.3 893 137 1837 Scour 0.0 0.2 774 876 601 PAD 0.0 0.0 835 840 831 1.0 PPA 4.1 5.2 414 619 838 .0 PPA 5.0 5.1 337 472 224 .0 PPA 5.0 5.1 294 384 235 .0 PPA 5.0 5.2 315 381 235 5.0 PPA 5.2 5.2 252 253 247 10 .0 PPA 5.2 5.3 4320 381 236 11 .0 PPA 5.0 5.2 2 511 325 12 .0 PPA 4.3 5.0 4356 553 4B2 13 Clear Lines 19.2 0.0 664 908 2 14 Ball 0.0 .0 026 109 0934 Schlumberger -Private Scmumbergcr Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States Average Treating Pressure: 4122 psi Maximum Treating Pressure: 5137 psi Average Injection Rate: 22.1 bbVmin Maximum Injection Rate: 25.3 bbVmin Average Horsepower: 2279.7 hhp Maximum Horsepower: 2830.8 hhp Maximum Prop Concentration: 7.5 PPA Section 2: Stage 4: Job Messages Schlumberger -Private Message r, Y Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Hate (bbl/min) Prep. Conc. (PPA) 1 10:42:27 Reset Executed Steps I I 0. 0.1 0. 2 10:42:27 Reset Executed Steps I 1 01 0. 0. 3 10:55:39 Priming up pumps X 32 0. 0.1 0. 4 11:17:54 Pumps are primed. 17 0. 0. 0. 5 11:18:14 Recirc line is knocked off 17 1 0. 0. 0. 6 11:32:59 Low PT 28 35711 01 01 0. 7 11:35:23 Coming up to 4K 2511 3496 01 01 0. 8 11:39:42 Checking outthe lines 431 345 0. 0. 0. 9 11:40:45 Coming up for high PT 438 341 0. 0. 0. 10 11:42:25 Leak on high pressure cap 177 328 0. 01 0. 11 11:55:56 Coming up for high PTagain 4 12C 01 0. 0. 12 12:07:31 High PT is good. 674 114 01 0. 0. 13 12:07:53 Bleeding off pressure 640 114 01 0. 0. 14 12:08:29 Getting gathered up to have a safety meeting 4 114 0A 0. 0. 15 12:49:41 Safety meeting is over/mixing gel 11 241 O.0 0. 0. 16 12:51:43 Priming up on gel fluid 12 243 0.1 0.1 0. 17 13:DD:17 Matching the wellhead pressure 1554 241 0.1 0.0 0. 18 13:01:04 Opening Well 743 241 0. 0.0 0. 19 13:01:36 Displacing the diesel 739 241 0.1 0.1 0. 20 13:01:39 Start Ball Automatically 740 241 Oc 0.0 0. 21 13:01:39 Start Propped Frac Automatically 740 241 0. 0.0 0. 22 13:01:39 Start Stage 4;PorAutomatically 740, 2411 0. 0.0 0. 23 13:01:45 Started Pumping 704 241A 0. 0.0 0. 24 13:13:39 Start PAD to st be Manually 297 251 32, 12.3 0. 25 13:19:29 ctivated Extend Stage 505 2501 114.1 18.7 0. 26 13:20:52 Stage at Parts: Ball 4028 242 140. 19. 0. 27 13:22:28 Stage at Ports: PAD to st be 27 238 172. 16. 0. 28 13:22:47 Coming off line to figure out xlink issue 22 237 174. 1.1 0. 29 13:33:53 Deactivated Extend Stage 379 256 237. 20.1 0. 30 13:33:53 Start Scour Manually 379 256 237. 20.1 0. 31 133353 Started Pumping Pro 379 256 237. 20.1 0. 32 13:40:54 Stage at Parts: Scour 386 254 378. 20.01 D. Schlumberger -Private Schlumberger Client: BP Alaska Well: S-189 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States Schlumberger -Private Message Log # Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbUmin) Prop. Conc. (PPA) 33 13:43:53Start PAD Automatically 363 257 438. 20.0 0. 34 13:44:53 tart 1.0 PPA Automatically 3852 256 458. 20.0 0. 35 13:49:54 tage at Perfs: PAD 4416 25 578. 25.0 1. 36 13:49:54 tart 2.0 PPA Automatically 4416 255 578.3 25.0 1. 37 13:50:42 tage at Perfs:1.0 PPA 4455 258 598.3 25.0.2. 38 13:54:41 tart 3.0 PPA Automatically 4240 259 697. 25.0 2. 39 13:55:31 tage at Perfs: 2.0 PPA 4356 255N 718.7 24.9 3. 40 13:59:29 Start 4.0 PPA Automatically 4241 259 817. 25.0 3. 41 74:00:18 Stage at Perfs:3.0 PPA 4347 255 838. 24.9 4.1 42 14:03:44 ctivated Extend Stage 4272 252 924.1 25.1 4. 43 14:04:27 Deactivated Extend Stage 4260 252 942. 25.2 3. 44 14:04:28 tart 5.0 PPA Automatically 4256 2531 942. 25.2 3. 45 14:04:36 Start 5.0 PPA Manually 4243 2521 946. 25.2 4. 46 14:05:05 Stage at Perfs:4.0 PPA 4319 253 958.1 25.2 5.1 47 14:09:24 Start 6.0 PPA Automatically 4328 253 1066.9 25.2 5. 48 14:10:02 Stage at Perfs:5.0 PPA 4426 2550 1082.8 24.9 6. 49 14:10:10 Stage at Perfs:5.0 PPA 4363 2539 1086.2 25.0 5. 50 14:14:15 Start 7.0 PPA Automatically 4426 2492 1188.1 25.0 6. 51 14:14:28 Activated Extend Stage 4406 2498 1193.5 25.0 6. 52 14:15:01 Stage at Perfs:5.0 PPA 4432 2486 1207.225.0 7. 53 14:17:26 Deactivated Extend Stage 346 235 1265. 79.2 0. 54 14:17:26 tart Clear Lines Manually 346 235 1265. 19.210. 55 14:18:29 tart Ball Automatically 426 243 1285.7 20. 0. Schlumberger -Private scmumbemer Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country: United States Section 3: Stage 5: As Measured Pump Schedule Average Treating Pressure: Stage Maximum Treating Pressure: 5656 psi Average Injection Rate: As Measured Pump Schedule Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Minimum Treating Pressure Pressure (psi) (psi) 1 PAD to st be Step # Stop Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name PMraax Cone op (PPA) Prop Cone (PPA) Prop Mass (lb) 1 PAD 143.9 18.1 8.7 YF128FIexD 6043 18.8 0.4 00 D87 2 Scour 79.2 13.3 6 YF128FIexD 3254 100 Mesh Sand 0.5 0.5 2137 3 PAD 94 16 5.9 YF128FlexD 3945 585 0.1 0 0 4 1.0 PPA 100.2 18.8 5.3 YF128FIexD 4033 Carbo Lite 16/20 1.1 1 409 5 12.0 PPAI 100.11 20.1 51 YF128FIexD 3870 CarboLite 16/20 2.1 1.91 775 6 3.0 PPA 99.N 22.9 4.3 YF128FIexD 3702 Carbol-ite 16/20 3.1 1123 7 4.0 PPA 111. 23. 4. YF128FlexD 398 CarboLite 16/20 4.1 3. 1616 8 5.0 PPA 101 23. 4.3 YF128FIexD 3451 CarboBond Lite 16/20 5.4 4. 1813 9 6.0 PPA 94.3 22.2 4.3 YF128FIexD 325 CarboBond Lite 16/20 6. 4. 1651 10 Clear Lines 7.5 22.2 0. YF128FIexD 31 0 11 Ball 1 22.2 0.1 YF128FIexD 42 0 12 Displace 3 13.9 0.2 YF128FIexD 1681 Average Treating Pressure: Stage Maximum Treating Pressure: 5656 psi Average Injection Rate: Step # Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Minimum Treating Pressure Pressure (psi) (psi) 1 PAD to st be 18.1 23.11 t492 026 3078 Scour 13.3 15.2 093 5176 4921 PAD 16.0 18.0 5080 5195 4914 1.0 PPA 18.8 19.8 5060 D87 4803 5 2.0 PPA 0.1 1.8 5 203 952 0 PPA 2.9 3.3 14 5176 768 .0 PPA 3.3 3.3 709 801 585 .0 PPA 3.3 3.4 10 1 506 .0 PPA 2.2 .4 58 995 35 10 Clear Lines .6 10.8 1975 56 6 Average Treating Pressure: 4804 psi Maximum Treating Pressure: 5656 psi Average Injection Rate: 19.7 bbl/min Maximum Injection Rate: 23.8 bbl/min Average Horsepower: 2326.8 hhp Maximum Horsepower: 2905.0 hhp Maximum Prop Concentration: 6.9 PPA Schlumberger -Private Scmumberger Section 4: Stage 5: Job Messages Client: BP Alaska Well: S-109 Formation: Kuparuk District: Prudhoe Bay, AK Country. United States d Time Message Message rr Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate Slurry bbVmin) Prop. Conc. (PPA) 1 14:18:32 Start PAD to st be Automatically 4352 243 0. 21.4 0. 2 14:18:32 Start Propped Frac Automatically 4352 243 0. 21.4 0. 3 14:18:32 Start Stage 5; Por Automatically 4352 243 01 21.4 0. 4 14:19:00 Stopped Pumping Pro 4659 20 101 23.7 0. 5 14:20:26 tage at Paris: 6.0 PPA 4179 2421.42.1 19.3 0. 6 14:24:34 ctivated Extend Stage 4921 2570 114. 12.5 0. 7 14:24:55 tage at Paris: 7.0 PPA 4967 2590 118.7 11.3 0. 6 14:26:45 Stage at Paris: Clear Lines 492 260 136. 10. 0. 9 14:26:50 tage at Perfs: Ball 4920 260 139. 10. 0. 10 14:27:00 tarred Pumping Prop 4935 260 141.7 11.0 0. 11 14:27:11 Deactivated Extend Stage 4864 2 143.7 11.0 0.1 12 14:27:11 tart Scour Manually 4864 256 143.7 11.0 0.1 - 13 14:33:09 tart PAD Manually 514 256 222. 15.2 0.1 14 14:33:17 ctivated Extend Stage 5148 2561 224. 15. 0.1 15 14:33:21 topped Pumping Prop 5128 2561 226. 15.2 0. 16 14:36:51 tage at Perfs: PAD to st be 5032 25 280. 16. 0. 17 14:38:53 tarted Pumping Prop 5060 256 314. 17.9 0. 18 14:39:00 Deactivated Extend Stage 5093 255 316. 18.3 0. 19 14:39:01 Start 1.0 PPA Automatically 509 251 316. 18. 0. 20 14:41:18 tage at Paris: Scour 5068 254(.359. 18.7 1. 21 14:44:22 Start 2.0 PPA Automatically 5178 2597 417. 19.7 1, 22 14:46:14 tage at Parts: PAD 5135 256N 453.N 19.8 1. 23 14:49:21 tart 3.0 PPA Automatically 5003 2544 517.N 21.9 2.1 24 14:50:58 tage at Paris: 1.0 PPA 5143 2571 553. 22.6 3.1 25 14:53:42 tart 4.0 PPA Automatically 4769 254 617.1 23.3 3. 26 14:54:02 Activated Extend Stage 4741 253 624. 23.3 3. 27 14:55:18 Stage at Paris: 2.0 PPA 4726 254 654. 23.3 4.1 28 14:58:27 Deactivated Extend Stage 4580 249 727. 23.3 4. 29 14:58:28 Start 5.0 PPA Automatically 4590 249 728. 23.3 4. 30 14:59:34 Stage at Paris: 3.0 PPA 454q 247 753.7 23.3 5. 31 15:02:49 Start 6.0 PPA Automatically 46371 2457 829. 23. 4. 32 15:04:20 Stage at Paris: 4.0 PPA 45561 2541 864. 23. 6. 33 15:07:08 Start Clear Lines Manually 465N 247 923.A 8.1 0. 34 15:07:19 Stopped Pumping Prop 49IN 251 924. 7.1.0.1 35 15:10:55 Screened out 4321 239 926. 0.1 0. 36 15:13:42 Shutting in the well 4221220 926. -0. 0. 37 15:13:59 Well shut bleeding pressure 4221 926. -0. 0. 38 15:24:03 Cleaning up pumps 27 934. 6. 0. 39 15:34:41 Started Pumpin 71 934. 0. 0.40 15:34:58 Gettin read to um diesel down the well 7 934. 0. 0. 41 16:11:16 ell shut bleedingyressure 4971 934. 0. 0. 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Z E ? m U O N w U O F Z o Z c « O p N u7 rn V a m N (0 N N a w t E 0 0 CL E O U a LL C 3 m m ii u .7 m T N (D a a LL C v (D % @ O CD c 3 H m 3: o Z a) NN cu m ro N m O N U O F E 0 0 CL E O U a LL C 3 m m ii u .7 m T N G 4) E E O U c « O p N u7 rn V N N N (0 N N X LL ca Co U2� C O .0 o U E > y > Eco D E R O V a 9 C C C O '- c U E E m N Q UQUZU N M N � J Xmm_ N T WD a owD � O C � QI N C N O o O c a U— Q = m Z UQ d rn m n CL E E U > L L N U E m Z N a f0 y _ O L065 Schlumberger Scale Inhibitor Listed Below S100 Schlumberger Fluid Loss Additive Listed Below S522-1620 Schlumberger Propping Agent Listed Below S526-1620 Schlumberger Propping Agent Listed Below J580 Schlumberger Gelling Agent Listed Below J475 Schlumberger Breaker Listed Below M275 Schlumberger Bactericide Listed Below F103 Schlumberger Surfactant Listed Below S123 Schlumberger Activator Listed Below J604 Schlumberger Crosslinker Listed Below M002 Schlumberger Additive Listed Below ove are Trade Names with the exception of Base Water. Items below are the individual Ceramic materials and wares, chemicals ingredients. 66402-68-4 92.45725 20.87227 Quartz, Crystalline silica 14808-60-7 4.02320 0.90824 Guargum 9000-30-0 1.22301 0.27609 2-hydroxy-N,N,N- thmethyleth ana minium chloride 67-48-1 0.55664 0.12566 Ulexite 1319-33-1 0.46881 0.10584 Ethylene Glycol 107-21-1 0.35349 0.07980 Diammonium peroxodisulphate 7727-54-0 0.26467 0.05975 Propen-2-ol 67-63-0 0.15422 0.03481 Alcohols, cl 1-15- secondary, ethoxylated 68131-40-8 0.09039 0.02041 2-Propenoic acid, polymer with sodium phosphinate 129898-01-7 0.07677 0.01733 2-butoxyethanol 111-76-2 0.06383 0.01441 Ethoxylated C11 Alcohol 34398-01-1 0.05862 0.01323 Vinylidene chloride/methylacrylate copolymer 25038-72-6 0.05738 0.01295 Sodium Tetraborate Decahydrate 1303-96-4 0.05182 0.01170 Sodium hydroxide (impurity) 1310-73-2 0.04819 0.01088 Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water " Information is based on the maximum potential for concentration and thus the total may be over 100% If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) Ethoxylated Alcohol 68131-39-5 0.03182 0.00718 Sodium chloride 7647-14-5 0.01550 0.00350 but-2-enedioic acid 110-17-8 0.01234 0.00279 Calcium Chloride 10043-52-4 0.00783 0.00177 Diatomaceous earth, calcined 91053-39-3 0.00609 0.00138 Undecanol 112-42-5 0.00511 0.00115 Non -crystalline silica (impurity) 7631-86-9 0.00307 0.00069 Magnesium silicate hydrate (talc) 14807-96-6 0.00175 0.00040 Magnesium nitrate 10377-60-3 0.00122 0.00028 2,2"-oxydiethanol (impurity) 111-46-6 0.00083 0.00019 poly(tetrafluoroethylene) 9002-84-0 0.00075 0.00017 5 -chloro -2 -methyl -2h- isothiazolol-3-one 26172-55-4 0.00065 0.00015 Magnesium chloride 7786-30-3 0.00061 0.00014 Diutan gum 125005-87-0 0.00062 0.00014 Diutan 595585-15-2 0.00062 0.00014 Potassium chloride (impurity) 7447-40-7 0.00025 0.00006 Acetic acid, potassium salt 127-08-2 0.00019 0.00004 2-methyl-2h-isothiazol-3- one 2682-20-4 0.00020 0.00004 Cristobalite 14464-46-1 0.00012 0.00003 Acetic acid (impurity) 64-19-7 0.00003 0.00001 Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water " Information is based on the maximum potential for concentration and thus the total may be over 100% If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) 41/16" CNV WE-LHEAD= FMC ACTUATOR= CNV SH OKE. E_EV---------- 644• BF. E_EV =_ 37.02' KOP= 200' Max Angle = 1010 @ 11513' Datum MD= 8445' Datum TVD= 670(Y SS 19-5/8• CSG, 40/0. L-80. D = 8.835' 1 Minimum ID =1.625" @ 10792' FRAC PORT SLEEVE #2 14-12- [BG, 12.60, L-80, .0152 bpf, D = 3.958' 1 TOP OF 2-7/8" LNR PERFORATION SUMMARY REF LOG: ANGLEATTOPPERF. 74'@ 7898' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 3-3/8" 12 7898-7901 O 06/22/03 4147 2-7/8" "4-6 7950- B040 O 04/03/03 10792 2-7/8" '"4-6 8050-8170 O 04/03/03 DMY 2-718" '"4-6 8300-8400 O 04/03/03 63 2-7/8" "4-6 8430-8540 O 04/03/03 7419 2-7/8" "4-6 8650-8780 O 04/03/03 0 2-7/8" "4-6 8820-9150 O 04/03/03 3-3/16" 10 8934-8975 O 11/18118 412" SLTD 9406-11428 SLOT 01/17/03 --rul rp uu19D W 13 -CR .0152 bpf, D = 3. .611. L-80..0152 bof. D = SAFETY TL W S-109 HO ON AELL***2-7/3- /ANGLCHROME LNR'•" 228W H4-12- HES X NP, D = 3.813' 7487' HBKR CMD BX PROFILE SLD SLV, I 7662' 1--17" X 4-12' BKR PREM PKIZ D = 3 1 9289' 1 4-1/2' HES XN NP, D = 3-725- 7"X .725•7'X 5' BKR FLEX LOCK HGR & ZXP LTP, D= 4400- 4-1/2' WLEG, D=4,000' BMD TT NOT LOGCN37 3.70• DEPLOYMENT SLEEVE, D MARKER JT W/ RA TAG 14-12• BKR INDICATOR PROFILE SUB, D= 3.850' 1 4-12- BKR NDCATOR PROFLE SUB. D = 3.850' PAYZONE PC PKR. D = LINERPACKERS FRAC PORT SLEEVES NO DEPTI-I D 6 GAS LIFT MANDRELS 2.03" ST MD TVD I DEVI TYPE I VLV I LATCH IPOF 9576 4 4147 38181 28 1 KBG-2 DMY BK0 10792 3 5531 5010 29 KBG-2 DMY BK 0 2 7309 6495 63 KBG-2 DMY BK 0 1 7419 6558 57 KBG-2 DMY BK 0 7487' HBKR CMD BX PROFILE SLD SLV, I 7662' 1--17" X 4-12' BKR PREM PKIZ D = 3 1 9289' 1 4-1/2' HES XN NP, D = 3-725- 7"X .725•7'X 5' BKR FLEX LOCK HGR & ZXP LTP, D= 4400- 4-1/2' WLEG, D=4,000' BMD TT NOT LOGCN37 3.70• DEPLOYMENT SLEEVE, D MARKER JT W/ RA TAG 14-12• BKR INDICATOR PROFILE SUB, D= 3.850' 1 4-12- BKR NDCATOR PROFLE SUB. D = 3.850' PAYZONE PC PKR. D = LINERPACKERS FRAC PORT SLEEVES NO DEPTI-I D 6 7742 2.03" 5 7919 2.03" 4 9195 2.03" 3 9576 2.03" 2 10136 2.03" 1 11346 2.03" NO DEFrH D DOTE 6 7887 1.875' 1121/18 5 8952 1.813" 1121118 4 9503 1.750" 1121/18 3 10105 1.688" 1121/18 2 10792 1.625' 1121/18 1 11425 1.930" 1121/18 12-7/6' FLOAT SHOE I DATE 01/16/18 0424/18 12/12/18 12/19/18 01/10/19 01/10119 REV BY I COMMI NfS AURORA UPIT GJB/JMD GLV C/O(01/09118) WB -L S-109 ZV/JMD GLV GO (0423/18) PERMIT No: "2022450 AB/JMD RAN LNR&REPERF(11/18/18) API No: 50.029-23135-00 TFA/JMD ADDED FRAC PORTS 8 PKRS SEC 35, T12K R12F- 813' FNL & 787 FWL AB/JMD COR-BaTKM TO WBS JNJJMD ADD BF, EDIT 9-5/8" DEPIH, TYPO ON PERF DEPTH BP Exploration (Alaska) DATE REV BY COMMENTS 01/17/03 DAC/TLH INITIAL COMPLETION 0224/03 TWKAK DEPTH CORRECTIONS 01/16/14 DJ,S/JMD GLV CIO(01/08/14) 1220/16 JGL1JMD SET PNM PLUG (12/14/16) 1221/16 KFYJMD TREE GO(1220116) 1227/16 ZV/JMD PULLED PXN PLUG (12122/16) 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-109 Acid Cleanout Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-245 50-029-23135-00-00 11600 Conductor Surface Intermediate Liner Liner 6794 80 3001 7794 3824 3726 11438 20" 9-5/8" 7" 4-1/2" 2-7/8" 6793 30 - 110 29 - 3031 26 - 7820 7646 - 11470 7719 - 11445 30 - 110 29 - 2849 26 - 6741 6666 - 6818 6699 - 6822 None 470 3090 5410 7500 11160 None 1490 5750 7240 8430 10570 7898 - 11428 4-1/2" 12.6# L-80 24 - 7653 6768 - 6824 Structural 4-1/2" Baker Premier Packer 7552, 6624 7552 6624 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, AURORA OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028257 24 - 6669 2-7/8" Liner from 7850 - 11438 Pump 18.2-bbls 15% HCL acid. Final treating pressure =3000-psi. 277 Well Not Online 555 546 1716 1150 225 300 N/A 13b. Pools active after work:AURORA OIL No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:45 am, Dec 15, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.12.15 07:23:20 -09'00' Torin Roschinger (4662) WCB 5-10-2024 DSR-12/18/23 RBDMS JSB 122623 ACTIVITY DATE SUMMARY 12/3/2023 T/I/O = SSV/1930/140. Temp = SI. Bleed IAP (pre CT). ALP = 1940 psi, SI @ CV & LV. Wellhouse floor kit removed. IA FL @ 2790' (4629'above sta # 1 SO). Bled IAP to S-117 production to 1450 psi. IA FL inflowed 1030' to 1760' (5659' above sta # 1 SO). Monitored for 30 min. IAP increased 90 psi, IA FL inflowed 90' to 1670' (5749' above sta # 1 SO). Stacked IAP to 1940 psi in 1 hr 30 min depressing IA FL 380' to 2050' (5369' above sta # 1 SO). Final WHPs = SSV/1940/140. SV, WV, SSV = C. IA, OA = OTG. 01:30 12/4/2023 LRS CTU 1, 1.5" Blue coil, Job Objective: FCO, Caliper, & Perf MIRU. Pump 1" drift ball. Review well entry. BOP test 250/4000psi. Function BOPs on well. Make up slim FCO BHA. Cannot bullhead. RIH and fluid pack the well by circulating a bottoms up. Jet with hot diesel from 7200' to 7878' before a hard tag. Pick up and unable to get past 7850'. POOH to pick up a motor / mill. ***Job in Progress*** 12/4/2023 LRS 72 Assist CTU. (CLEAN OUT) Pumped 240 bbls of 150*F diesel into the coil reel. CTU in control of well and pad op notified upon LRS departure. ***Performed Fire Drill*** 12/5/2023 LRS CTU #1, 1.5" Blue Coil. Job Objective: FCO, Caliper, Perf Troubleshoot LRS generator issues. Repair and RIH with 1.77" diamond parabolic milling BHA. Dry tagged at liner packer 7740 CTM and spin through. Cleaned out what appeared to be fill down to hard tag at ~7850'. Unable to mill through. Drop circ sub ball and chase gel OOH. Perform injectivity test at surface (0.2 BPM at 2500 psi). RBIH slim with 1.50" DJN. Tag at 7770'. Start pumping diesel and prepare to pump acid. ***Job in Progress*** 12/6/2023 LRS CTU #1, 1.5" Blue Coil. Job Objective: FCO, Caliper, Perf Pump 18.2 BBL's of 15% HCL acid and displace with diesel. While circing in acid, able to jet down to the original tag/milling depth of 7850'. Once the acid got to the nozzle, able to RIH freely to 7900'. Circ'd in 8 bbl's, picked up to the liner top, and pumped 2 bbl's down the coil / liner, allow to soak. Pump 1 more bbl down the liner. RIH and drift cleanly to 9000'. Pick back up to the liner top and displace the remaining 7 bbl's of acid in the coil down the liner, allow to soak. Displace the remaining 8 bbl's of acid on the CTB into the liner, allow to soak. Overdisplace with KCL at 1.9 bpm @ 980 psi. SD pump and RIH. Tag @ 11,462'. PU to 11,300. uanble to RBIH. PUH to 9500' and circ 10 bbl 2.25# gel sweep while RBIH. Tag @ 11462'. Circ 2nd 10 bbl gel sweep and POH @ 80% performing FCO. Pump rate1.6 bpm. Maintain return rate @ 1.2 bpm. FP coil and bullhead 38 diesel . Final injectivity .3 bpm @ 2400 psi. Rig up HES Caliper and RIH. Set down @ 7910'. Attempt to bullhead down back side then coil to get passed with no success. Pump down coil taking returns and able to get through. PUH and dry drift clean, continue in hole. Hard tag again at 9528' and unable to get passed. Log from 9528' CTM to 7650'. POOH and confirm good data. Appears to be scale from the liner top to ~ 9050'. RDMO. ***Job Complete*** Daily Report of Well Operations PBU S-109 While circing in acid,g able to jet down to the original tag/milling depth of 7850'. Once the acid got to the jggg g nozzle, able to RIH freely to 7900'. Circ'd in 8 bbl's, picked up to the liner top, and y pumped 2 bbl's down the coil / liner, allow to soak. Pump 1 more bbl down the liner. RIH and drift cleanly to 9000'. Pick back up to the liner top and displace the remainingy 7 bbl's of acid in the coil down the liner, allow to soak. Displace the remaining 8 bbl'sg of acid on the CTB into the liner, allow to soak. Overdisplace with KCL at 1.9 bpm @ @ 980 psi. SD pump and RIH. Tag @ 11,462'. PU to 11,300. uanble to RBIH. PUH to g@ 9500' and circ 10 bbl 2.25# gel sweep while RBIH. Tag @ 11462'. Circ 2nd 10 bbl gelgg@g sweep and POH @ 80% performing FCO. Pump rate1.6 bpm. Maintain return rate @@g@ 1.2 bpm. FP coil and bullhead 38 diesel . Final injectivity .3 bpm @ 2400 psi. Rig up jy @ g HES Caliper and RIH. Set down @ 7910'. Attempt to bullhead down back side then @ coil to get passed with no success. Pump down coil taking returns and able to getggg through. PUH and dry drift clean, continue in hole. Hard tag again at 9528' and gy gg unable to get passed. Log from 9528' CTM to 7650'. POOH and confirm good data.gg Appears to be scale from the liner top to ~ 9050'. RDMO to pick up a motor / mill. y Jet with hot diesel from 7200' to 7878' before a hard tag. g Pick up and unable to get past 7850'. POOH g Dry tagged at liner packer 7740 CTM and spin through. Cleaned out rgygg g what appeared to be fill down to hard tag at ~7850'. Unable to mill through. Drop circgg sub ball and chase gel OOH. Perform injectivity test at surface (0.2 BPM at 2500 psi). gjy( RBIH slim with 1.50" DJN. Tag at 7770'.Start pumping diesel and prepare to pump acid. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other Scab Liner 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work5. Development 0 Exploratory ❑ Permit to Drill Number 202-245 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-23135-00-00 7. Property Designation (Lease Number): ADL 0282578. Well Name and Number. PBU S-109 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, AURORA OIL 11. Present Well Condition Summary: Total Depth: measured 11600 feet Plugs measured None feet We vertical 6794 feet Junk measured None feet Effective Depth: measured 11600 feet Packer measured 7554 feet true vertical 6794 feel Packer true vertical 6624 feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 79 20" 31-110 31-110 1490 470 Surface 3002 9-5/8" 30-3032 30-2850 5750 3090 Intermediate 7794 7" 27-7822 27-6742 7240 5410 Production Liner 3824 4-1/2' 7646-11470 6666-6818 8430 7500 Perforation Depth: Measured depth: 7898-11428 feet True vertical depth: 6768-6824 feet Tubing (size, grade, measured and true vertical depth) 4-1/2' 12.6# L-80 25-7654 25-6670 Packers and SSSV (type, measured and 4-1/2' Baker Premier Packer 7554 6624 true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mct Water -Bbl Casing Pressure Tubing Pressure Prior to well operation Shut -In Subsequent to operation: No Test Available 14.Attachments: (mquiretl par20 PAC 25.07025.071,&25.203) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 317-499 Authorized Name. Thompson, Ryan Contact Name: Thompson, Ryan Authorized Title: Interventions Engineer Contact Email: RYAN.THOMPSON(dlbp.com Authorized Signature: Date: I Z 11 f /1g Contact Phone: +1 907 564 4535 Form 10-404 Revised 04/2017 f4&2 IAW T'i RBDM§2aXC 17 2018 Submit Original Only ***WELL S/I ON ARRIVAL*** (Well Platform) DRIFT TO DEVIATION @ 7898' SLM w/ 3.70" CENT & 2.5" SAMPLE BAILER PERFORM SBHP PER PROGRAM... GOOD DATA SET 4-1/2" PXN PLUG @ 7640' MD SET 4-1/2" WHIDDON CATCHER @ 7621' SLIM 4/21/2018 *"CONT. ON 04/22/2018 WSR*** ***CONT. FROM 04/21/2018 WSR*** (Well Platform) PULLED BK-S/O @ 7419' MD ATTEMPT TO PULL STA# 3 SEVERAL TIMES, FISH NECK IS STRIPPED SET BK-DGLV @ 4147' MD SET BEK-CIRC VALVE @ 7419' MD RAN OVERSHOT AND PULLED STA# 3 BK-LGLV @ 5531' MD SET BK-DGLV @ 5531' MD LRS CIRC OUT IA/TBG 4/22/2018 `**CONT. ON 04/23/2018 WSR T/1/0=730/500/100 (LRS Unit 42 -Assist Slickline: Circ Well, MIT -T, MIT -IA, Injectivity Test) Pumped 5 bbls 60/40 followed by 100 bbls crude followed b y 168 bbls Inhibited 9.8 NaCL down IA taking returns up the TBG and out the flowline. Freeze protected IA with 45 bbls crude. 4/22/2018 **Continued on 4/23/18 WSR** ***CONT. FROM 04/22/2018 WSR*** (Well Platform) PULLED BEK-CIRC VALVE @ 7419' MD SET BK-DGLV @ 7419' MD PULLED CATCHER @ 7621' SLM MIT -T PASSED MIT -IA PASSED PULLED 4-1/2" PXN PLUG @ 7640' MD 4/23/2018 ***JOB COMPLETE, LEAVE WELL S/I FOR FRAC*** **Continued from 4/22/18 WSR** (LRS Unit 42 -Assist Slickline: Load & Test) Pumped 4 bblsl 60/40 down FL for FP. **MIT -T ***PASSED*** to 3907 psi**, Max Applied pressure = 4000 psi, Target pressure= 3600 psi. Pressured TBG to 3996 psi with .81 bis crude. MIT -T lost 66 psi in 1st 15 minutes and 23 psi in 2nd 15 minutes for a total of 89 psi during 30 minute test. Bled TBG to 25 psi. **MIT -IA ***PASSED*** to 3681 psi**, Max applied 3700 psi, target 3330 psi. MIT -IA pumped 2.1 bbls crude down IA to reach test pressure. 1st 15 min IA lost 25 psi. 2nd 15 min IA lost 10 psi for a total loss of 35 psi in 30 min. Bled IAP. Bled back - 2.1 bbls. RDMO. SL in control of well upon LRS departure. Caution and info tags hung on IA/WV. IA/OA= 4/23/2018 OTG. T/1/0= 820/115/115 Temp=S/I (LRS Unit 42 - Injectivity Test) Establish injectivity of -1760-1850 psi @ 5 bpm w/ 5 bbls 60/40 followed by 185 bbls of 1 % KCL down TBG for Injectivity test. See log for details. Freeze protected TBG with 40 bbls crude. RDMO. Swab/SSV/WV=Closed MV=Open IA/OA=OTGAL=closed. Hung tag on WV. 4/24/2018 FWHP's=1300/250/220 Cost placeholder for camera system on wellwork platform 4/26/2018 7/11/2018 Cost placeholder for upcoming WWP job. Daily Report of Well Operations S-109 Cost place holder for 2-7/8" safety joint machining 7/27/2018 ***WELL S/I ON ARRIVAL***(pre frac) STBY FOR DEWATERING 8/23/2018 ***CONT ON 8-24-18 WSR*** ***CONT FROM 8-23-18 WSR***(Pre frac) DRIFTED W/ 2.72" CENT & SAMPLE BAILER TO DEVIATION @ 8050' SLM.(no sample) 8/24/2018 RAN SBHPS PER PROGRAM W/ BP DUAL SPARTEK GAUGES IN CARRIER.(good TWO = 1400/0/0. Barriers for setting TWC = SV x SSV (LTT). RU CIW Lubricator 68-840 with setting tool and TWC #432. PT'd to 3500 (PASSED) Ran down and tag @ 120". Set TWC and performed LLT (PASSED). RD Lubricator. Barriers for SV removal = TWC x MV. RD SV and installed tree cap. Torqued to API specs. PT'd tree cap 300 PSI Low (PASSED) and 5000 PSI High (PASSED) charted and retained. RDMO. SEE LOG FOR 9/9/2018 DETAILS. FWHP T/I/O = TWC/0/0 ***Job Complete*** 10/2/2018 Cost placeholder for upcoming work. 10/19/2018 Cost placeholder for machine work on S-109 TWO = TWC/50/100. Temp = SI. WHPs (pre wellwork platform). Flowline & AL disconnected. Wellwork platform rigged up to well. No heater running at this time. 11/10/2018 RU in control of valves upon departure. 22:30 CTU #9 - 2.375" Coil - Wellwork Platform Job Objective: Add Perf, Run Liner MIRU CTU. 11/12/2018 ***Job Continued on 11/13/18*** CTU #9 - 2.375" Coil - Wellwork Platform ***Continued from 11/12/18*** Job Objective: Add Perf, Run Liner Continue riggin up/testing stuff. MU bop test joint. Complete system function test of entire bop stack and HCR. Begin BOP test. 11/13/2018 ***Job Continued on 11/14/18*** CTU #9 - 2.375" Coil - Wellwork Platform ***Continued from 11/13/18*** Job Objective: Add Perf, Run Liner Continue bop test 11/14/2018 ***Job Continued on 11/15/18*** CTU #9 - 2.375" Coil - Wellwork Platform ***Continued from 11/14/18*** Job Objective: Add Perf, Run Liner Finish practice bop test. Begin D1 drills. 11/15/2018 ***Job Continued on 11/16/18*** CTU #9 - 2.375" Coil - Wellwork Platform *"*Continued from 11/15/18*** Job Objective: Add Perf, Run Liner Perform unwitnessed AOGCC state bop test 11/16/2018 ***Job Continued on 11/17/18*** TWO = BPV/0/0 Pulled TWC #432 through BOP stack of WWP w/ lubricator 68-840 with 11/17/2018 15' Ext. @ 120". RDMO ***Job Complete*** CTU #9 - 2.375" Coil - Wellwork Platform ***Continued from 11/16/18*** Job Objective: Add Perf, Run Liner Complete unwitnessed AOGCC state bop test. MU/RIH with HES 2.88" logging carrier (GR/CCUPress/temp). Tag PBTD at 11465CTM and log up to 7000. Pipe flagged at 8900'. Performed three stop counts for BHP/T at 8183, 7724, & 7504. POOH. 11/17/2018 ***Job Continued on 11/18/18*** Daily Report of Well Operations S-109 CTU #9 - 2.375" Coil - Wellwork Platform ***Continued from 11/17/18*** Job Objective: Add Perf, Run Liner Continue POOH. OOH with logging tools and have good data showing a +9' correction making corrected EOP at flag = 8897.33, and the PBTD 11473.57'. MU/RIH with 40' loaded 3.18" 10spf 135/45deg phase HMX 0.67 EH/4.7"penetration Power Flow charges. Re -perforate 8934-8975 (41' of shot coverage due to 1' gap between the guns). Re- configure lubricator. Lay down mast. Begin loading floor with Doyon equip etc, start loading liner. 11/18/2018 ***Job Continued on 11/19/18*** CTU #9 - 2.375" Coil - Wellwork Platform `*`Continued from 11/18/18*** Job Objective: Add Perf, Run Liner Make up and RIH with 2.875" GR/CCUPRESS/TEMP Carrier with 3.700" JSN. Perform well kill. Unable to perform well kill as per SOR (could not circulate holding 100psi over static without incurring losses). Killed well volumetrically/laid in pert pill from 11472' to 7350', Pump pipe displacement + a little while pooh. Perform flow checks as needed before popping off/laying down logging tools. Good log data +6.5'. Corrected PBTD=11473.57'. Begin deploying liner. 11/19/2018 ***Job Continued on 11/20/18*** CTU #9 - 2.375" Coil - Wellwork Platform ***Continued from 11/18/18*** Job Objective: Add Perf, Run Liner Make up and RIH with 2.875" GR/CCL/PRESS/TEMP Carrier with 3.700" JSN. Perform well kill. Unable to perform well kill as per SOR (could not circulate holding 100psi over static without incurring losses). Killed well volumetrically/laid in pert pill from 11472' to 7350', Pump pipe displacement + a little while pooh. Perform flow checks as needed before popping off/laying down logging tools. Good log data +65. Corrected PBTD=11473.57'. Begin deploying liner. 11/19/2018 ***Job Continued on 11/20/18*** CTU #9 - 2.375" Coil - Wellwork Platform ***Continued from 11/19/18*** Job Objective: Add Pert, Run Liner Continue deploying liner. 11/20/2018 ***Job in Progress*** CTU #9 - 2.375" Coil - Wellwork Platform ***Continued from 11/20/18*** Job Objective: Add Perf, Run Liner Continue deploying liner. RIH with liner and set. Perform pressure test on CTBS to confirm set to 2015psi - pass. Shear out lowest frac port at 4200 psi and establish injectivity. Unsting and POOH. Well freeze protected with 38bbl of 60/40. OOH with liner running tool and all looks normal. RDMO. Ran and set 3726' Six Stage Frac Packer Liner 2-7/8" 6.5# 13cr VAM TOP connections. Top @ 7719'. Bottom @ 11,445' 11/21/2018 ***Job Complete*** CTU #9 - 2.375" Coil - Wellwork Platform ***Continued from 11/21/18*** Job Objective: Add Perf, Run Liner RDMO. 11/22/2018 ***Job Complete*** TWO = 0/0/0 Made change out with day crew. Torqued the upper tree to API -specs. PT 11/24/2018 upper tree. see to ) RDMO*** job complete**` TWO = SSV/0/100. Temp = SI. WHPs & measurments for up coming (rack. AL SI @ CV, ALP = 1900 psi. From treecap flange to middle of SSV = 47", from treecap flange to middle of master valve= 69" and from treecap to LDS on tubing head= 91" and from treecap to LDS on I/C = 117". 12/6/2018 1 SV, WV, SSV, MV = C. IA, OA = OTG. TRFF= 4-1/16" CW VWLLFEAD= FMC ACRIATOR= CMVSH OKB. ELEV = 64.4' BE EP/ = KOP= ------ 39' 200' Max Angle = 101" @ 11513' Datum MD= 8445' Datum TVD= 67W SS 19-5/8' CSG. 409. L-80. D = 8.835" 1 Minimum ID =125" @ 10792' 2-7/8" SCAB LINER 14-12' TBG, 12.69, L-80, .0152 bpf, D= 3.958' S-109 SAFETY NOTES: W ELL ANGLE > -70' LID 7870'. HORIZONTAL W E.L �IIRr1• 9_518• TAM PORT COLI AR 't$ 4-1/2" HES X NP, D = 3.813" GAS LIFT MANORE-S SEE LNR TALLY FROM 11/21/18 FOR SCAB LNR INFO = 6.278" PERFORATION StANVARY REP LOG: ANGLEATTOPPERF: 71'@ 7858' We: Refer to Production DB for historical pert data ST MD TVD DEV TYPE VLV 33/8' FORT DATE 7858-7901 O 0622103 4 4147 3818 28 KBG-2 DMY 0 04/23/18 "4b 1 t 04/03/03 3 5531 5010 29 KBG-2 DMY TBK 0 0423118 "4-6 8430- 8540 O 04/03/03 2 7309 6495 63 KBG-2 DMY 0 01/08114 "4-6 8820-9150 O D4/03/03 33/16' 1 7419 6558 57 KBG-2 OW SLTD D 0423/18 SLOT SEE LNR TALLY FROM 11/21/18 FOR SCAB LNR INFO = 6.278" PERFORATION StANVARY REP LOG: ANGLEATTOPPERF: 71'@ 7858' We: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpNSgz SHOT SOZ 33/8' 12 7858-7901 O 0622103 2-7/8' "4t 7950-8040 O 04103/03 2-7/8' "4b 8050-8170 O 04/03/03 2-7/8" "4-6 8300 - 8400 O 04103/23 2-7/8" "4-6 8430- 8540 O 04/03/03 2-718" "4-6 8650- 8780 O D4/03/03 2-7/8' "4-6 8820-9150 O D4/03/03 33/16' 10 8934-8975 O 11/18/18 4-11T SLTD 9406-11428 SLOT 01/17/03 W 11154) 3I[cll::y1jjzI BX PROFILE SLD SLV, D = 3.813' BKR PRET WJI D = 3.875" iX NP, D=3.813' S XN NP,D=3.725' 0R FLEX LOCK NGR & D = 4.400' 771x• H 2-7/8- TOP SCAB LNR D =1.25" D = 3.958' 14-12' BKR INDICATOR PROFILE SUB, D = 3.850' 4-12' BKR INDICATOR PROFILE SUB. D = 3.850' 11445' 2-7/8" BOT SCAB LNR, D' 125' AURORA LW VH3L S-109 PB;MT /11:"1022450 AN No: 50-029-23135-00 SEC 35, T12N, R12E, 813' FTL & 782' M DATE REV BY COMWBNTS DATE REV BY COMMENTS 01117103 DAC/TLH INITIAL COMPLETION 01/16118 GJB/JMD GLV C40(01/09/18) 0224/03 7KKAK DEPTH CORRECTIONS 0424/18 ZV/JMD CLVC40(0423/18) 01/16/14 OJS/JMD GLV 00 (01/08/14) 12/12/18 AB/JMD SCAB LNR&FEPEW(11/18/18 1220/16 JGUJMD SET PXN FLl1G (12/14/16) 1221/16 KA'JMD TREECJO(12rMI6) BP E1iploration (Alaska) 1227/16 ZV/JMD R LLED PXN PLt1G (1222/16) 410 • p TO aoz - 2-45 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday, May 15, 2018 10:27 AM To: 'Thompson, Ryan' Subject: PBU S-109(PTD 202-245, Sundry 317-499) Well Work Platform BOP Configuration Change Ryan, The change in BOP configuration outlined below is approved. Please include this approval with the approved Sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation CommissionJ 333 W.7th Ave �� � Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppna alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it o you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From:Thompson, Ryan [mailto:RYAN.THOMPSON@bp.com] Sent: Monday, May 14, 2018 5:35 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Subject:S-109 Well Work Platform Sundry Edit Victoria, We are planning to use a different BOP configuration than submitted in the sundry in execution of running a scab line on well 5-109 with the Well Work Platform. The change is to use Liner pipe/slips instead of Variable Bore Rams(as shown in the edited BOP schematic attached). Please let me know if you need anything further for this request to be approved. Thanks Ryan Thompson Well Interventions Engineer 907-564-4535 1. . • 0 i Platform Floor Riser to platform floor • _._ Annular f`�� !!� 111111111 it. I'l r Blind/Shear se Ili Hydraulically Actuated aive I , , I •iaIiiilliii Goll PieSliR NI Choke Line I ('. 0 -1Ifi`11 ‘'11 I I (r•"""' III V if" '''ll Kill Line 11610, lilior ow r tti,� 10110 ,1111 4 liner Pipe/Slip 1111E. , : �gii , I Coil Pipe/Slip ?x?Spool 1 ii 1 @ !; ssv it144 ii)yl ,1 Ma'.ter�Ialve i�I III`"APTMA tel! 1 w I II M_ - a I I ATubing Mead �.., Ground leve! 1 • • Pro ,ROz —z95_ Loepp, Victoria T (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Wednesday, April 04, 2018 10:09 AM To: Loepp,Victoria T(DOA) Cc: Leemhuis, Jacob Subject: FW: Change of rig for sundry#317-499 on S-109 (PTD#202-245) Attachments: Nabors CDR2 BOPE Stack - Bighole (11-21-17).pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Please use this updated BOP, not the previously sent version. This sundry was originally approved to be completed with the well work platform, however, it will now be completed with CDR2.There are no other changes other than the rig BOP stack. Please let me know if you have questions or need additional information. Thank you, %AHMED MAY 1 7 218 Joe Lastufka SIM Specialist Cell: (907) 227-8496 I Office: (907) 564-4091 S I M Subsurface&Welk. BP Exploration Alaska I 900 E. Benson Blvd. I Room: 778C I Anchorage, AK 1 • • Well Bighole CDR2-AC 4 Ram BOP Schematic Date 21-Nov-17 Quick Test Sub to Otis t t ti Top of7"Otis — — — — — — — — — • — .A1111111 IIII II. 111 ' '4CDR2 Rig's Drip Pan Distances from top of riser NM Excluding quick-test sub MI pi4 7-1/16"bk Flange X 7"Otis Box Top of Annular 6.0 ft minimomr Hydril 7 1/16" Top of Annular Element 6.7 ft Annular Bottom Annular I 8.0 ft I 01. fTT„T.. N. CL Blind/Shears ► p • �p 1 2-3/8•'Pipe/Slips CL 2-3/8"Pipe/Slips 10.1 ft ►1.... ..mt' B1 I B2 83 I B4 Choke Line Kill Line moos IF,. 7511,11,6d7511,11,6d „� *,,4 .,. I .1 m . wa kr . ha. Cross III ill 238"x312 VBRs 111. CL 2-3/8"x 3-1/2”VBRs 12.6 ft ;11.1► w a +el'`� i 2-31t"Pipe!Sltps CL 2-3/8"Pipe/Slips 13.4 ft �. im' CL of Top Swab 16.0 ft �► litig. 4--Swab Test Pump Hose Ai T1 1T2 CL of Flow Cross 17.4 ft - •4• 41‘• • ' *�4 ` Master CL of Master 18.8 ft LDS .. . ,. . a IC 11. IA '7i r rr 11 it lir II .Ii. OA Anrumnrumm rnn LDS 4, Ground Level I • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, December 22, 2017 12:31 PM To: AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS WELL PAD S;AK, OPS Well Pad SW;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Frankenburg,Amy; Youngmun,Alex; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel,Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer S-109 (PTD#2022450) Sustained inner annulus casing pressure above NOL Attachments: 5-109.pdf All, Producer S-109(PTD#2022450)was reported to have sustained inner annulus casing pressure above NOL on 12/21/17. The pressures were reported to be 200/2200/150psi. The sustained inner annulus casing pressure is an indication of a potential failure of one or more well barriers. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan forward: 1. Slickline—Gas lift change out 2. Fullbore—MIT Please respond with any questions, Joshua Stephens SCANNED Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO .w,..0_.I«.,...,..�., 1 VOF 77.4 • • yw,��\ //j,,SA THE STATE Alaska Oil and Gas 71, of LAsKAL Conservation Commission : _�== 333 West Seventh Avenue ittGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ain: 907.279.1433 ALAS MFax: 907.276.7542 www.aogcc.alaska.gov Ryan Thompson Interventions Engineer BP Exploration (Alaska), Inc. or PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S-109 Permit to Drill Number: 202-245 Sundry Number: 317-499 Dear Mr. Thompson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis. S. French Chair DATED this day of December, 2017. REDMS '- CCC C 8 2617 RECEIVED STATE OF ALASKA Ill lat LASKA OIL AND GAS CONSERVATION COMMI N OCT61S 1 1 2017�� • APPLICATION FOR SUNDRY APPRO 20 AAC 25.280 Z 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 own 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Scab Liner in-WP 0• 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 202-245 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ®, • 99519-6612 Stratigraphic 0 Service 0 6. API Number 50-029-23135-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No El PBU S-109 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028257 • PRUDHOE BAY.AURORA OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 11600 • 6794 • 11600 6794 1989 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 31-110 31-110 1490 470 Surface 3002 9-5/8" 30-3032 30-2850 5750 3090 Intermediate 7794 7" 27-7822 27-6742 7240 5410 Production Liner 3824 4-1/2" 7646-11470 I 6666-6818 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7858-11428 6755-6824 4-1/2"12.6# L-80 25-7654 Packers and SSSV Type: 4-1/2"Baker Premier Packer Packers and SSSV MD(ft)and ND(ft): 7554/6625 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary El Wellbore Schematic B 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch El Exploratory 0 Stratigraphic 0 Development El ' Service 0 14.Estimated Date for Commencing Operations: November 15,2017 15. Well Status after proposed work: Oil El • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Thompson,Ryan be deviated from without prior written approval. Contact Email: RYAN.THOMPSON©bp.com Authorized Name: Thompson,Ryan Contact Phone: +1 907 564 4535 Authorized Title: Interventions Engineer Authorized Signature: Date: /ob?/` 7 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test V Mechanical Integrity Test 0 Location Clearance 0 31 -7 _g9l Other: y �-o 5-U v 3�P fiz'S/ f err+ r-r Z 5° 0 P If-hr7vlar pr 5 Post Initial Injection MIT Req'd? Yes 0 No ET Spacing Exception Required? Yes 0 No CI Subsequent Form Required: /0 4-0 f- pp y APPROVED BYTHE l, A roved b : �� COMMISSIONER COMMISSION Date: t Z- ck `� v'T•L iZ`6'//� .i- ORIGINALREE: ,3 Ltiit� Cir C crrleL \ti Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ,.r/ ,.," ,e,•/7./7 by • 0 Sundry Request To Run Scab Liner Utilizing The Well Work Platform Well: S-109 Date: 10/16/2017 (Resubmitted with edits 11/28/17) Engineers: Alex Youngmun: 907-564-4864 Ryan Thompson: 907-564-4535 MASP: 1989 psi Well Type: Producer Estimated Start date: November 2017 History: S-109 is a horizontal gas lifted producer drilled in 2003 with a partial slotted liner completion. Scope of Work: The objective of this intervention is to utilize Service Coil and the Well Work Platform to run a scab liner with frac ports and swell packers in order to perform a fracture treatment post scab liner. The Fracture treatment job has been submitted as a separate sundry application. Proposed WWP Procedure: • MIRU WWP, BOPE and support equipment • MIRU CTU • Test BOPE with four preventers configured top down (annular, blind shears, 2.375" pipe/slips, mud cross, 2-3/8" x 3-1/2"VBR's, 2.375" pipe/slips). Test the blind shears, VBR's, and pipe slips to 3500 psi and the annular to 2500 psi. • Jet proposed frac intervals below: a. Jet perf holes at 11,350', 11,335', 10,800', 10,785', 10,100', 10,085' and 9500', b. Two locations per frac stage 15' apart will be jetted in the 4 1/2" slotted liner. c. Jetting fluid will consist of 1% KCL, HEC gel and 20/40 river sand. • Run 2 7/8" scab liner to TD @—11,470' MD. See scab liner tally attached. a. Scab liner to be hung off on Liner Hanger @—7750' MD. b. Scab liner to include 5 packers to isolate frac stages. c. Scab liner to include 6 fracports for future frac operations. • RDMO WWP and Coil Unit • • Current Wellbore Configuration ii-d4-= 4..1116'( N ._.__A vvtL..t�D= rnr' S-61 09 YY sar�TYtvox�:wELLANr�E3-tp•,�,rsro•- ACTUATOR- tawsaid HORI ?ONTAI F31. CAB HIV_ 64 4'': lei.FiCV- 39`' KS ' 7tXY' ` 1030` I—I0-5.18"TAM PORT COLLAR (Mats AnyjIc= 101"ft 11513'' (filum M)- 5445' ' I --2283'—1 4-112'FES X NP,D=3.613" I Munn WYI)- broil`Ss. I9-5!8"CSC 4{m,t.-80,V=Bt3t5' 1 I 3031r GAS LIFT MAN S ST M) TVD DEV TYPE VLV LATCH PORT DATE 4 4141 3818 28 1330-2 LX)ML' UK 15 06130./93 :i 553i 5010 79 KHC3.7 IXC-` HK 15 06/310/93 2 7309 6495 63 XEIG 2 C#* ' BK 0 01!86/14 1 , 7419 6558 57 KBG 2 SO I BK 24 07113103 __,-7or HEKR CMO 13X PROFILE SLO SLY.D-3.813' i Minimum ID=3.725"@ 7640' III 4-112 HES XN NIPPLE r_ 766r HrX4-112-9KRPREMPKR,0-3:875" - p ' ' i._..7811r'......H4-1,2"RES XNV,D=3.813'..,1 I I 1 76.14' I.---F1/7111.9 XN MP,113-3 725• 4_1!2"TBG,126#.1--90, 0152 NM,ID=3 958" I 7651Mi ZXP LTPO 4 ' 7 8' 7'X 5'81(R F 4 4 LACK HC3R& � . 406" n6 °7 14-112"1MLEG u=4 000' _________HELM)TT NQT L0GGF3� —, 0 lb. TBUr....HMAt Jr YUP°4A TAG t fi r'( 1,?IN,, 140,U-6.16' 1 ' 7820' I ' 815` I..14-1Kr=UM MICA I OR I TIKX 1 I Stift,1)"'1859*i 14-RH84A11(314SIJI RY REF LOG 9288__' ...I.14-112"BKR P40 AT0R PROFLE ,0= '0 3 850 ANGLE AT TOP PEW: 71'0 7858' / 1 11300' 'HKR PAY 700(FE'MR,in-3 937' Note:Refer to Production CO for historical pert data SIZE SPF NTH3HAL Opn'Sgz SHOT S3Z '. 3-318' 12 p 7658-7901'. 0 > 3 '.. 2-718' "4-6' 7950-8040 0 04/03/73 '^ 2-718' "4-6' 80550-8170 0 043 `• `.`. 2-718` -'4-6 8303-8400 0 (1-4 303 '. ,, 9-700 "4-6 9430-8640 0 04/83103 2-718' "4-6: 8650-8780 0 0403/03 7-70F "4-6' 8870-9150' 0 04/03/133 4 1/2" 51 IL//194 0 6 114281 6101 0111 1103 '"PUREPERF Guts USED 1> 4-1!2"LNR,12 68,L-80,0152 bpi,13=3 958' —I 11470' 1- 'g. DATE REV 1W COMMENTS DATE REV BY COMMENTS AUF40RA INT 1 01117103 17ACFTLH INITIAL COMPLETION 10/11113 MBMJPO GLV(20(130213) 'IA L.5-109 02101103! JC/ATP CYO GLIB 01/16114 DWr°'J.1) GLV CYO(01,08114) 1+34.11 No:2022450 102/24/03 11 VKAK OMIT 1 COFFECTISIZ 12/20116 4.1611-14) SET PXN PLUG(12/14/16) API No:50-029-23135-00 104/03163 JAF/TJ! ADD PURE FffFS 12/21/16 KA'JI/D TREE C/0(12/20/16) SFC 35 T12N R12E 613'FNL&782'FW 04/00/03 DRS/TP TVD/MD CORRECTIONS 12/27/16 ZVIJMD PULLED PXN PLUG(12/22/18) 0612203 Elk I.M'TLti ADD FERPS&FA STDRIL BP ___I BP Exploration(Alaska) • 0 Planned Wellbore Configuration Post Scab Liner TRa , ,• r` 044 r 1440- 9alift 11 la TM"WW1.Walt ACTUCCA- " -109 WW1104RAI WR t '000 art- L'•-t, HIV ,Was Ateik- . r ts,111, I tall' -,- urfauscorfmt.fAff' Dimrt tv0, ,,,"Yr V, , 0ralolirniirir:r41T- , ,--- 4-5or•:.:.X"..10 ..44 0-4 31‘ -:.'? ,"-- I t 54,5 kfl 1404311S 1 SI IV ram Iry' tv Po- Av "i A z01 RIO :0,11. 44? 3104 X ii 442 CAVE' ix li %Min 3 *31 S313 s i oac.2..I ow iiK is atm 1 2 MX __ a' 1502 1 0,1* ic 0 01X0114 i _ ....._... I Nil Ph5.4 57 , AW:1! RI .44 A 41'4103 Miniitu m Pr)0 3.7 25-ft 76,40' 1 4-1/2'liES XN NIP PLE 1 Ili • F.-4—r' -toot too st molt 34030%0-3 ar 1 ii.tit 40.4 11.41 Ow Ill.3 Iti* I f—iiiii --1-17 ttl,t qt,t i t tr isr,--tor 4.10 te•-t,..40 r r ,...- WSW r o Y 4.0431Eqi 1- I..c t1. 432444 0-3 alr ---4 7161" ZAT'Llr,0-4 0/ _ t i___ ...... 1 , 1 k71117 , 441111.044.7.N.1 YV.44 iko i ilif....•X* ANGLE AT TOPPOW l'S'a rose . Me Fle4er 0 Poltdirk 133 kr Ilimmil medal) •1 1SIVI ,---- . I gar -4 1'I tAX f“..Alf..4f-4041 VJP9 V#J let- .`,,Vi SU- OWN& i L,4764543 r ; %iv ')yr . .2 :"%r - 1 . ; alitt -4-t7 taqvi MCA 3Cgt Agit.E 34.6 0*3 WV. 2 71.7* -4-C, ;VC-Oa 0 01033413 „i4f--, "44 We 4130 0 044303 • I $31;47 j iSK4 tykYZONE IIC Po.0*3/or I , 2 Jr -44 akI•IWO 0 003303 "N. 2 Pr "*4t 14X $40 0 04,020 , 344r -4 4 03,.(.Va 0 040303 Ai, 40.4.s solo itwwwws 24Ir "44, IC(,1150 0 OW101 s ." .. .10, a-D XX•31,470 , 0a °VIP= . • *- on 4sc•RIK pars • —. ' .., nijfe.WW.G111104010 • • 4.100, , 44rr 3/JUD..4.i.*2M.LAE MU ret 0.)ie w H . . Ali ..., alik WAR ha I cur mom:i oft 12 se tax 013.2 H'"4-,.ifirio; ,......--, 1irii--111FirTT AIJ WI 'Iiiiral Clotol`41 WW1 Calft.LTX44 uS1v+1 teu.avavcr3io:oczno cavol mr to,:iL% 3 041^10(AY wfamic ' vow'iv tuaiw Linton ft-I-swot (31,14(.0164:C106 AMP. '414241,7ti kl.-LX .-- . . 00303:„K§rtil 1.X F1113015. 3C f.,TI:14 RIX.ill t Fit 3 13.7 Po% 1 XV403 tiectft• re:110a1134eitte. . :['1.11.7.4•3 iflic14 r ALI:RMS.&FAS,I JILL NO HP implants=Mask* i '---" - • 0 BOP rig up Platform Floor Riser to platform floor Tat Annular lim. i IIII,RF •1,iloi. Blind/Shear t i' Hydraulically Actuated Valve y ;_ I ;; -; I) Iu M an 1Coil Pipe/Slip illi IIiiI1O Choke Line i i ••;'*,1111��' � Yi '1 , / Kill Line l,.iv . O©,,,4., 1/4._ - NiIIiiII �l i m i ; Variable Bore Ram ,i mit ,Al 'mall. i1,1, Coil Pipe/Slip 7 x 7 Spool as needed Gil Flow Cross ' SSV /�tf r0/.��'.1 Master Valve ' THA ..,..1I I , o ; , ill Tubing Head . : Ground Level • • Proposed S-109 Liner Tally Mons tT®AOasrsplm Ntludas:Sg0.TYPE On 42) CONNECINI I -__ REM TOP 8009004 80 00 LENGTH TOP l0ROM COMMENTS Deployment Sleeve 31/2°SLPin 3.000 3.500 6 7737 7743 Baker Cross Over 31/1'511 Box Vam Top Pin 2370 3.510 2 7743 7745 Baker PadtersPhis02-G11deCerwdker N/A 3.650 0 7745 7745 0 PackerPkrs Hydraulic Set Nud6F1LL HS Parker,Mon Mal w/Bronze Backups Vam Top Vam Top 2.® 3.625 5 7745 7750 Liner Hanger,3pin @636ps1/pin,1908 psi cliff pxkarsPko Qblide Ceitr.Bser N/A 3,650 0 7750 7750 2-7/8"651113C8 8UnerPup Vam Top Vam Top 2259 2.875 4 7751 7754 2-7/r 65R13CIIB0Uner Pop Vam Top Vam Top 2.259 2.875 10 7754 7764 2-7/8°64213CP80 Liner(4101160 Vam Top Vam Top 2.259 2.875 120 7764 7884 2.7/r 55213CRB0 liner Pop Vam Top Vam Top 2.259 2.875 4 10 7884 7894 PaclaosPh6OrINabk FradORT,Mon Seals Vam Top Vam Top 1.686 3.$00 5 7894 7889 ...5146 116)Seal 1875,84811938°5F-7 2-7/r 65613062880 Una.Pap Vam Top Vam Top 2.259 2.875 10 7859 7909 2-7/1r 6 84 130880 liner(lOJo6M1s) Vam Top Vam TOp 2.259 2.875 300 7907 820 2.7/6°652130880liner Pup Vam Top Vam Top 2.259 2.875 10 - 8203 8219 Packers*.Nydran84 SetRockSEALIFMOpenhole Mal element pada@ Vam Top Vam Top 2.030 1625 5 8219 8224 Packer/151 7pin @356 psi/pin,2492 psi OM 2-7/°65613CI1813UMr Pup Vam Tap Vam Top 2.299 2.875 10 8224 8234 2-7/r 65613CB80Uner(23Joints) Vam top Vam Top 2.259 2.875 880 8234 8824 27/8"694 13038011n Pup Vam Top Vam Top 2.259 2.875 10 8924 8934 PackersPkis Od0abk FranPORT,VIIa8Saek Vam Top Vam Top 1.685 3.500 5 8934 M39 Sap 6S)Seat 1613",BM:1975"567 2.7/8°650 13[840 Liner Pup Vam Tap Vam Top 2.259 2.875 10 898 8949 2.7/r 6921303801Mer(99oeMs) Vam Top Vam Top 2.259 2.875 240 8949 9189 2.7/6"65*13C8801.1ner Pop Vam Top Vam Top 2.259 2.875 10 9189 9199 Ptla0Pbuflpdrrdlc5et148856A161110 enhole dual element mast Vam Top Vam Top 2.030 3.625 5 9188 9204 Packer*kj 7 pin 4935690/Ido,2482psi diff 2-7/r 6901312001Uwr Pup Vam Top Vam Top 2.259 2.875 10 9204 9214 2-7/8"6.8413CR80 Liner(9joink) Vam Top Vam Top 2259 2875 270 9214 9484 2-7/8°651/1300/80 Liner Pup Vam Top Vam Top 2.259 2.875 10 9484 9494 • PaNamPlnu 0998000 FrasPORT,Man Se* Vam Top Vam Top 1.688 3.600 5 9094 9099 Stade 89 Seat 1750',Bail:1875"973 2-7/4"65213CJM01.1ner Pup Vam Top Vam Top 2.259 2.875 10 9459 95C9 2-7/r 658 13011300n Pup Vam Top Vam Top 2.251 2.875 10 9509 9519 1V/6°69113CItpikner(39Ants) Vam Top Vam Top 2.259 2.875 9D 9519 9609 2.7/r 65613CbDuner Pup Vam Top Vam Top 2.59 2.875 10 9608 9619 PadesPku NydraioSet Roed9AU14470p808414 o4oMmempgker Vern Top Vam Top 2.032 3.625 5 9619 9624 Packer63)7pin @356Psi/pin.2459psi cliff 2.7/8"63/113CM0 Utter Pup Vam Top Vam Top 2.259 2.875 10 9624 9634 2-7/r 691 MUM liner(15jobits) Vam Top Vam Top 2.259 2.875 450 9634 10084 2-7/r 65213CRWUerpup Vam Top Vam Top 2.259 2.875 10 10084 10094 PatkenPk046394044 FniNPORF,Vl6e Auk Vam Top Vam Top 16811 3.500 5 16086 10099 Stage 63)Seat:168x,Bab:1750"5F-7 2-7/r 65613C080Unwrhp Vern Top Vam Top 2.259 2.875 6 10099 101(0 2-7/r 0.5013aM0 lineri5jolnts) Vam Top Vam Top 2.259 2875 150 10106 10255 24/8°65tllCR80Uner Pap Vam Top Vam Top 1239 2.875 1010255 r 10266 Pac8uPNss HydtaiRc8at R0i0)AL IFHMaMar TOpeele dual element Vam Top Vam Top 2.030 3.625 5 _. 10266 10270 Pack*r82)7pin @ 356 psi/pin,2492 psidiff 2.7/11.65813[1393 Utter Pup Vam Top Vam Top 2.259 2.875 10 10270 10280 2-7/r 65213CTM01AM(17JWnu) Vam Top Vam Top 2.299 2.875 510 10280 10790 2.7/8°650130t000ner Pup Vam Top Vam Top 2.259 2.875 10 10793 10810 __ Palms**01108048 k.IP007.V12419Sok Vam Top Vam Top 1625 3.500 5 10800 10805 Stage 425 Seat:1.625°,Ban:1.6f1r SF-7 2-7/6°6311130120Ueer(9jWM2) Vam Top Vam Top 2.259 2.875 270 1085 11075 2.7/9 6.591301110U8oPup Vam Top Vam Top , 2.259 2.875 10 11075 11085 PaherkesHmteaenSetlb4WAL 8SPadar,Mon Seal Mamas 8adtps Vam Top Vam Top 2.030 3.625 5 1185 11090 Packer*If 7 pin @35678/pin,2492 psi cliff 2-7/8"65213CRBOUner Pup Vam Top Vam Top 2.259 2.875 10 11090 11100 2.7/8°65813CABpIMr(8jolnk) Vam Top Vam Top 2.259 2.875 240 11100 11340 2-7/8°65813CWO Liner Pup Vam Top Vam Top 2.299 2.875 10 11340 113°0 PadwnpWs El-Cillo Centralizer N/A 3.650 4 0 11350 11359 Stage 6i)Upper SLY:Spins @ 833ps1/pin(416 psis, Padiersmus Dual External 81draulic Fraport,Vitae elastomers Vam Top Vans Top 1.930 3.625 5 11350 11355 lower:a pins @S09 psi/pie(4072 psi) PackeosPlus 112-Glide Centrallter N/A 3.650 0 11355 11355 2-7/8°652130188Uner Pup Vam Top _ Vam Top 2.259 2.875 10 1135 1136 2.7/4"ESN 131:913DLkee(2)Oints) Vam Top Vam Top 2.259 2.875 60 11365 11475 2.716°6S613G8OUrwr Pup yarn Top Vam Top 2.259 2.875 6 11425 11431 2.7/0°13COPaBBersPkt The Onc Sub,KM Elastomers,MO Se*:189.8811900:159 Vam Top Vam Top 1.000 3.625 S 11431 11436 2pin @531 psi/ple.1062 psi Mit 1-7/8°1301pacleesPhu Float Collar Vam Top Vam Top N/A 3.688 3 11436 11439 2-7/r 658130180Uner Pup Vam Top Vam Top 2.251 2.875 6 11439 11445 2.7/0°13CRParkersPius Float Collar Vam Top Vam Top N/A 3.699 3 11445 11448 2.7/8°1301PakerPlus Bullet Nose Re-Entry Guide Vam Top N/A 1500 3.630 2 11448 11450 • 4440 • • .• • Sundry Request for Extended Length Perforating utilizing the Well Work Platform Well: S-109 Date: 10/16/2017 Engineers: Alex Youngmun: 907-564-4864 Ryan Thompson: 907-564-4535 MASP: 1989 psi Well Type: Producer Estimated Start date: November 2017 History: S-109 is a horizontal gas lifted producer drilled in 2003 with a partial slotted liner completion. - Scope of Work: The objective of this intervention is to utilize Service Coil and the Well Work Platform to run a scab liner with frac ports and swell packers in order to perform a fracture treatment post scab liner. The Fracture treatment job will be submitted in a separate sundry application. Proposed WWP Procedure: • MIRU WWP, BOPE and support equipment • MIRU CTU • Test BOPE with four preventers configured top down (annular, blind shears, 2.375" pipe/slips, mud cross, 2-3/8" x 3-1/2" VBR's, 2.375" pipe/slips). Test the blind shears, VBR's, and pipe slips to 3500 psi and the annular to 2500 psi. • Jet proposed frac intervals and tie in to PBTD • Run scab liner to TD • RDMO WWP and Coil Unit • • Current Wellbore Configuration 1141-- 4-1i18-[AV ____ ..._.v_....,.__.,...__.__....._._ .._._._..___...._._._.__.._._...._._. WELLHEAD= 111C1 SAFE rrrNOTES:WELL ANG,'LE>-70'6787D- ACTU4TOR- aww; S-'109 MORI7ONTALW11.1, DKR H.EV- 64.4'1 BE cV- 39` a K 7,��.. .. 1030' 9-50"TAM PORT COLLAR Mm,Angle.. 101"ofp 11513' Llaharn MJ-, 8145' 1 , I7il 2283' _4-1 rr P HES X.r ,LI=3 B 13' .: Datum IV - 6m00'SS, 1g-s8'C1( 400,L-80,0=9 835•}- 3030' GAS LFT 0.44NL1 5 iT M7 TVD DEV; TY FE VLV LATCH PORT DATE 0 4 4147 32518 26 j KBG2 1X .L 13K 16 06181'03 3 5:831 5710 75 KRt37 Ix)t f3K 16 06L 3'13 2 7309 6495 63 KJ3G2 Cfd( BK 0 0103/14 1 1 7419 f 6558 57 KBG 2 SC) BK 24 07113/03 F 748T f--r0+fR(CA[]6K PROFILE SLD SLV 0-1813' 1 Minimum ID=3.725"®7640' m 4-112"H E S XN N W P L E 7654 7-x 4-1/2 BKR PROM 1,102,ID.3.875" j I , 1 7919'. 1-f 4-1' FF3 X►P n=3913, I r �rms.k rv, - T'X 3'F KR FLE)f LOCX HGR 14-1/7 TRG,12.611,L-B0,-0152 W,ID=3 958' 7161' —_._-- .1l ZXPLTP,0=4401' --..,_�� 7653' 1-j4-U2'VVLEG,V=4.000' L—__ UK)TTNOT LDGGID J • 7 7/302 -1116418CER JT 1'64 4A TAG El 92I 14-1,9'RKR NX'A 1C94 PROF 1 FSIAL,1D•3 850' F31tTCNA 1KXiti11.l AK( F LW. 8209' 1 14-1T1•BKRPICY'ATORPROFILE SOB,0=3.850'0 ANGLE AT TOP PERE: 71' 7858' 0.-T 9300' I-+;OKR P.%Y 71150;Ft'PKR,0 3 737'..1 j Nate.Refer to Production CO for historical pert data SIZE SPF FliF37VAL QpdSrg SHOT SEY 3-318' 12 i7858 7901 , 0 06/22,03 '. 2-718' -4-61 7950-8040 f 0 (/4/(57/03 2-718" *4-61 8050-8170) 0 X 04/33103 2-118" "4-6 8300-8400 0 04/0-3.03 • 2-718' "4-6!8430-8540 0 04,0 1,03 `. 2-718 -'4-51 8650-8780 0 04/03103[13 2-718' "48 8820-9150 0 04✓03433. 41/2' SSLTD'9406 11428 SLOT 01111/03. "'PURE PHS GUNS L1360 14.112"LNR,12 L--80 0152 bp!,ID=7.95811--1 11470' FATE REV 3Y I DATE REV 3Y 001.44ENTF, AURORA 1.3.41- 01/17/03 .31 101117/03 Tk1C/TLH 1NTIAL COMPLETION 10/11/13 i143M'J11D GLV(70(1042/13) %ELL. 5109 (12/01f03 .1(1.41P CIO GI VS 01n6+14DL3S+,:M.1 GLV 00(01 114) FER1AT P.b 20224.50 f 01124/113 n WCT i AK L P1I I GTICIN 12/20116 JGU.A.4) SET PKU FL UG(12114116) API No. 50-029-2313500 04103,{03 ./ART-11 A DD PURE E FE#TS 12/21116'6 JMC I TI2IT-C/011200/16) SEC 35,T+T214 8121;813 FAI 8 782'FW '04/7`103 URS/IP 1-VCVACOORREVl43f4S 12)27/16 ZV/J/43IKILLED PXIMRUG(12/22/16) 0C/22f03}-61k1411_14,A130 PEWS B FA STDPI L RP i I 1 BP E ploratIon(Alaska) . II . Planned Wellbore Configuration Post Scab Liner , .. . . . . . ,.. ,eki ti4*0. ... SARIN VDTS.WRA.ANKH*-TV PI/V I!AMAX*- „ S 1 09 W36/11100 W 0 1 . - f kiroVagko- 'V no. 3/ 1-1-6P-4WVPS- -0010;111 I I ...1 1 cliksLriwolis f$17 w-ND mt. I,* i ',,,,w $$$$.2.2.( $.txo. $v*.m.:" t 1$42 VII 3 37!DOME ix. ' ii Di , SW SM IA *CI!D24( 0,,.. ' i 3 ,• ....3 1 2 ._ . 44 WtA S: osto../ 1 Sc) **(. A VI 101 Minimu rn 13 7640'§t 3.7257,f/ .. . . 44127 HES XN NIPPLE Mr ---itex cto sw vv/Plf 00'PA.0-)6,vii : ,..,,, ,,, i mit ..„,„4 4.f...r AM 64014iff444 Of 14f4g g II .4'4 -410.14.0 414)U..SW' 11 ,340 .44 gr.4f.4.44f.f f.I rits, • rkler TM,0 0I,LP. 015Ztii 0..11.00- H 7.141' .,, , ;fc2 14 0.7-w... l'i.so II f4 g. .2 04.40 TON'A OAP" . 101111 .1.1 Rff.X0 AW AT TOP 3...4r 71' r; 7301* Ntolv Peer 0 F*00.0100 IP.P1.0.0-x00 we tots I•I I troii loom*20.$.2i-44.,$t t;Iii;i7--"ocs.$ 1s1 tio * • 0$472w . wo. -*tr.$ taccootak mom&et 0*300:0'''' . . 24P -44 7KC-VO) 0 0VW1 zo 0 04/11.01 . .0 L 1300' 1--4 ,14kYZOW 3 cool,o-I uri 24ir •'4* XXiC. .. 0 fArJum UI? `.4.4 4X $40 0 ...4 .00. UP '-44 WO.V 0 04.°000 s ' *iv proasen 0 0410,,, I 2/V ''''** Me.100 0 WW1 ii, 31.76 WV-144211 0 tti v 14X2 ' j . * ,. 4.-yr sat)...$24,$2 CO.t-4/1.010 W.ID. % . *10.910100V0.17.**I,01,VS:WO.Mr 1142W of—iirfirliWi Mit Wolff 0.1104.000 (PR ó1c ....0.14160PS IOWA le ,'0110010•0114000000.00VPIXTV0V 1V3 le .30 Okv0V(Matit WEL fp 1,3) &OM i MATP 00 CC* 01.0P14 MAO 04Y14 .-,- 4. .t• .to ,..., tO r0Plialt PPArolV*1001TPt,—— — — 4110 0410 r340 140M01 WAN Ate MK' '-= Is r 3S.M3313 Sit ,3,343 1 OOSTP 0.34110.Vcrop6 rIAL.1.1 1048 I I A0341 10? : VP VOIVer.0044.0V00.10 , ... , . 0 • BOP rig up ..... ,. . ., .. , .. /0-4-4 .4— ......*. Platform Floor Riser to platform floor = , .ii walk titi Annular mil maim ' 1 t Blind/Shear Hydraulically Actuated Valve $ II - .....* 12 li 1 t 13 Coil Pipe/Slip II — L _A Choke Line ?) -.0., - m -PI` 041.:A 00°"'s 1$444 IV41))4 _ , _ t V.,er _ '' ° 4111 ".//-* Kill Line t • __Irt I) Variable Bore Ram 11.1.,1 II! 1111D I a ' Coil Pipe Slip Eti"b). 7 x 7 Spool as needed I L Flow Cross —I 1— SSV ll'arf''C 41, ird-.A1 ,Q00..-- Master Value .F-7.. •r THA . -v MI I WooPM A I Tubing Head g ... - -'-- -— '- - - - -- - ---- Ground Level 11111 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday, November 28, 2017 8:35 AM To: 'Thompson, Ryan' Subject: RE: PBU S-109(PTD 202-245, Sundry 317-499)Scab Liner w/frac ports Ryan, Please send a more detailed procedure. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.aov From:Thompson, Ryan [mailto:RYAN.THOMPSON@bp.comj Sent: Monday, November 27,2017 3:07 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: PBU S-109(PTD 202-245,Sundry 317-499)Scab Liner w/frac ports Victoria, • TOC for the 7" intermediate casing is 3150' MD(USIT log run 1/15/2003) • The FIT out of the 7"shoe was to 12.1 ppg(6753'ND) Please let me know if you need anything else. Thanks, Ryan From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, November 27, 2017 10:10 AM To:Thompson, Ryan<RYAN.THOMPSONt bp.com> Subject: PBU S-109(PTD 202-245,Sundry 317-499)Scab Liner w/frac ports Ryan, 1 4110 What is the intermediate 7"casing• ? What was the FIT out of the 7"? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp aa..alaskagov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation • Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loerr@alaska.gov • 2 Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday,June 20, 2017 12:47 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD 5; Bergene, Matthew; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer S-109 (PTD#2022450) Inner Annulus over NOL - Failed TIFL All, Gas lifted Producer 5-109 (PTD#2022450)exceeded NOL on the inner annulus and failing a subsequent TIFL on 06/19/17. Operations could not pop the well for a warm TIFL due to a pad shutdown. The current estimate for S pad to come back online is 06/30/17. At this time the well is classified as Under Evaluation,and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. Operations-POP well 2. Down Hole Diagnostics: Perform Warm TIFL 3. Well Integrity Engineer: Additional Diagnostics as needed Please respond with any questions, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Sat 3\iN 2 2'07, Harmony 4530 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,June 14, 2017 7:05 AM To: AK, GWO Well Integrity Engineer; Regg,James B (DOA) Cc: Wallace, Chris D (DOA);AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity Subject: Producer S-43 (PTD# 1970520) and S-109 (PTD#2022450) High Inner Annulus Pressure Over NOL after pad shutdown. Attachments: S-43.pdf;S-109.pdf Mr. Regg, Gas lifted producers S-43 (PTD#1970520),and 5-109(PTD#2022450)were reported over NOL on 6/13/17. The pressures were reported to be T/I/O=220/2018/S0psi for 5-109, and 220/2011/100psi for S-43. The high pressure event was discovered shortly after a pad shut down and appears to be caused by a spike in the gas lift supply header pressure. The plan forward is to bleed the IA and perform follow up monitors to ensure this is not an integrity issue; if we see any repressurization the well will be made under evaluation at that time. Please reply with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED J IN s��I i- W tw - 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,July 12, 2017 5:32 AM To: AK, GWO Well Integrity Engineer;AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD 5; Bergene, Matthew; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA) Subject: OPERBALE: Producer S-109 (PTD#2022450)Warm TIFL Passed All, Producer 5-109 (PTD#2022450)was made under evaluation on 06/20/17 for exceeding NOL and failing a subsequent cold TIFL. The well was recently brought online and passed a warm TIFL on 07/11/17. The passing test confirms two competent well barriers. The well is now reclassified as Operable. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 W QUI- 2r SCO WO gkobal.4414 From: AK, GWO tegrity Engineer Sent: Tuesday, June 20, 12:47 PM To: AK, OPS GC2 OSM; AK, OPS t. Field O&M TL; AK, OPS GC2 Wel[pad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; AK, OPS EOC Specialists; Cis i, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Be =-ne, Matthew; Regg, James B (DOA) (jim.regg@alaska.gov) Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Integrity; AKIMS App User; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; O. ..ewitch, Beau; Sternicki, Oliver R; Worthington, Aras J; AK, OPS FF Well Ops Comp Rep; 'chris.wallace@alaska.gov' Subject: UNDER EVALUATION: Producer S-109 (PTD#2022450) I •-r Annulus over NOL- Failed TIFL All, Gas lifted Producer S-109 (PTD#2022450)exceeded NOL on the inner annulus and fail' subsequent TIFL on 06/19/17. Operations could not pop the well for a warm TIFL due to a pad shutdown. The c -nt estimate for S pad to Image ...ìoject Well History File co~er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ p:J.. -:It¡:-:S Well History File Identifier Organizing (done) o Two-sided 1111111111I11111111 o Rescan Needed RESCAN DIGITAL DATA ~iskettes, No. ~ o Other NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: . BY: Helen ~ J .~ Date:3 3 06 /s/ MP Project Proofing BY: Helen~ Date: ð?>/ os-- /s/ m(J Scanning Preparation BY: Helen~ à. x 30 Joo , + l (0 = -OTAl. PAGES Zb (Count doe:s not i clude cover sh et) tvl, ,p Date: ß 3 J ()J- /s/ " t' Production Scanning I Stage 1 Page Count from Scanned File: 7 7 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES, NO Helen@ Date:3 3/ ().s- Isl M :J If NO in stage 1 page(s) discrepancies were found: YES NO Stage 1 BY: BY: Helen Maria Date: /s/ 111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned IIII II BY: Helen Maria Date: /s/ Comments about this file: Quality Checked III II 11111111111111 • • ~ BP Exploration (Alaska) Inc. Attn: Weil Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 ~ ~ Enclosed please find a spreadsheet with a list of welis from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, 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, .... i . . f:~ ~~~ ; ~yyp', Q yg~ N ! ' ti+~~V Y'~SY~i~Yli11~ t~ ~.l f.. i!. Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploration (Alaska ) lnc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) S-pad r ~A}P fi/25/2009 Well Name PTD X Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Cortosion inhibitor COROSIOfI inhibitod sealant date ft bbls ft na al S-Ot8 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 7.7 5/25/2009 5-03 1811900 1325 NA 1325 NA 92.65 5/20/2009 S-0a 1830790 0 NA 0 NA O.s SI25/2009 S-05A 1951890 0 NA 0 NA O.s 5/26/2009 S-os 1821650 0 NA 0 NA o.s 5/26I2009 S-07A 1920980 0 NA 0 NA O.s 5/26/2009 S-O88 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 1821040 1.5 NA 1.5 NA 9.4 5131/2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 5-118 1990530 025 NA 025 NA 1.7 5/27/2009 5-72A 1851930 025 NA 025 NA t.7 6l1/2009 S-13 1821350 8 NA 8 NA 55.3 6/1/2009 5-15 1840170 025 NA 025 NA 3 6/2/2009 S-17C 2020070 025 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6l2/2009 S-79 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 0.25 NA ~ 0.25 NA 1.3 5/19I2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25l2009 S-22B 1970510 0.75 NA 0.75 NA 3 5/19/2009 S-23 1901270 0.25 NA 025 NA 7.7 5/25/2009 5-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 S-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-27B 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-288 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL7 1960720 0 NA 0 NA 0.85 5/27/2009 S30 1900660 0.5 NA 0.5 NA 5.1 5/37/2009 S31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 5-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S33 i 921020 0.5 NA 0.5 NA 4.3 5/26/2009 S-3M1 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 5-35 1921480 0 NA 0 NA .85in 5/31/2009 S-36 1921160 0.75 NA 0.75 NA 425 5/27/2009 5-37 1920990 1.25 NA 125 NA 11.9 5/27/2009 5-38 1921270 025 NA 025 NA t02 5/27I2009 5-41 1960240 1.5 NA 1.5 NA 17.1 5/30/2009 S-a2 1960540 0 NA 0 NA 0.9 SI30/2009 S-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-44 1970070 025 NA 025 NA 1.7 5/28/2009 S-100 2000780 2 NA 2 NA 21.3 5/29/2009 S-101 2001150 125 NA 125 NA 11.9 5/29/2009 5-102L1 2037560 1.25 NA 125 NA 11.7 5/31/2009 5403 2001680 1.5 NA 1.5 NA 11.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 S-105 2001520 4 NA 4 NA 32.7 SI20/2009 5-106 2010720 16.25 NA 1625 NA t74.3 6/2I2009 5-707 2071130 2.25 NA 2.25 NA 28.9 5/18/2009 5-~08 2011000 3.5 NA 3.5 NA 40 5/30/2009 -709 2022450 2 NA 2 NA 21.3 5/30/2009 S-t70 2011290 1175 NA 1175 NA 99.6 5/30/2009 S-71t 2050510 2 NA 2 NA 19.6 5/30/2009 5-112 2021350 0 NA 0 NA 0.5 5/30/2009 5-113 2021430 1.75 NA 1.75 NA 22.7 5/18/2009 5-114A 2021980 125 NA 125 NA 102 5/30/2009 S-115 2022300 2.5 NA 2.5 NA 27.2 5/29/2009 5-~16 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 5-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-118 2032000 5 NA 5 NA 76.5 5/28/2009 5419 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-121 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 S-t22 2050810 3 NA 3 NA 27.3 5/29/2W9 S-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-124 2061360 775 NA 775 NA 11.9 5/26/2009 S-125 2070830 225 NA 225 NA 20.4 5/2fl/2009 5-126 20710970 1.25 NA 125 NA 15.3 6/1/2009 S-2oo 1972390 1.25 NA 725 NA ta.5 5/28/2009 5-207 2001840 0 NA 0 NA 0.85 6/19/2009 S-213A 2042130 2 NA 2 NA 13.6 5/29/2009 5-215 2021540 2 NA 2 NA 18.7 6/1/2009 5-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 S-217 2070950 0.25 NA 025 NA 1.7 6/1/2009 5400 2070740 2 NA 2 NA 9.4 5/28/2009 S-401 2060780 16 NA 16 NA 99.5 6/2/2009 5-504 0 NA 0 NA 0.85 5/28/2009 u P.l. Suprv ~ ~- Z Ito ~' Safety Valve & Well Pressures Test Report Reviewed B~ l Comm Pad: PBl1_S InspDt: 2/18/2008 Inspected by John Crisp Interval tnspNo svsJCr08022 1 1 40934 Related Insp: Field Name PRUDHOE BAY Operator BP EXPLORATION (ALASKA) INC Operator Rep Rich Vincent Reason 180-Day `~ Src: Inspector _ ,_ - _ Well,Datct __ Piluts ~ SSV ~ SSSV Shutln Dt~ We11 T e Well Pressures - _ ' ' -- ---- _ -- ~- - ---- ~---- -~-- -- ~L. ;ft L Waiver i CUtnrnents- Well Permit Separ Set L/P Test Test I Test Date S[ OiI,WAG,GINJ, Inner Ou[er Tubing ~ G(lS Ll~ _ - _ --_ `_-_-_ - Number Number PSI PSl Trip Code Code Code GAS,CYCLE, S( PSI PSI PSI Yes/No Yes/No _ _ _ S-100 S 103 S-105 S-106 S-108 ~'~ S-109 S-I 13 ' S-115 S-117 S-l2l S-122 S-125 S-17C S-18A . 5-213 5-44 . 2000780 - 2001680 ._. _ - a ! 2001 2 153 1 -_ i 53 -- - - 125 -..- 25 i J _- 125 -- 120 L---- I _ -- P -- - Y __ _ P - --- -l?-- _-. I -I ~---- r_.-___- __- -~ _-~ - -- - r- _-_.. _.___ 1 O(L ._ - - - 1-OIL - - ~ _ . -_~- -- --- - - r- __-. ~ --- ~ ~ --- - - - _ _ - --- --- -t i ~ __ - - ~-- ~- - -- --- 5 0 ~ I 2010120 i - ~ l53 -- l53 - 125 -- 125 110 40 -P 30 P P -~ 1-OIL 1-OIL -.~ ~ --~ ~ -- - - --- - __ _ __+ - __ - 2011000 ~ ~ 2022450 2021430 ~ 153 - 153 153 ~ 125 -- 25 1251 I l25 I 125 l25 P P P P P P t-OIL _ _ t -OIL l-OIL ! _ - -- - - .. , ( - -}- i - ~ 2022300 2030120 20604(0 - - 153 I 153 ~ 153 -- _-~ 125 125 125 120 - .. ! 135 125 P --- P P ~ _.._.-I P P P --- -- -- --- _ _ 1-O1L ~ 1-OIL 1-OlL ; ---~ ~ ! -- -- ~ ----- ----- ~ ----- _ ~ f. - - - ~ _i.____. - - 2050810 ~ -I ------- 2070830 - ~ - - - 2020070 i ~ 153 r !53 153 ~ l25 --- 125 - 125 ! - 110 - 115 I- - -- l10 - - P -- P - P ----- P -- P --- P ~- -- ---- --- ---~ -- - - - _.. -~--- - 1-O[L ~ ---- ~ 1-O(L .-. _. I-OIL -----t --- _ -- ---~ - . -. - - ---- -_. - ----- - ~, --._ ~ -- -- ' ~- - --- ...- -- ~ -I- ------ -- - ~ 2021630 ~ ~ 153 i ± -- --i 125 __ -- -- 100 - P P - -- - ~- _ ~ - - - - 1-OIL % - -- __ - - - 7 i -- --- -- - -- ~ - ~ _ i _ 2042130 ~ I 1970060 -~- -~--1 153 153 t -- ~ l25 125 -- 125 100 -~ P - P-- -- P ~P~ --- _-- ~ ~ ---- --' 1-O1L i 1-OIL ~ -- --- _ _ I _ _ _ _ I L - 1 _ r_-__ ~ B A _ _ --- r _~ 7 -- _ --- _ _- __--7 __ ! - -- --- - -~ ----- --- i --- __ _ _ _.-. -- - - - -1 Comments ~ ~r~ ~~, J ~~v«.~~,-- , ~ I e.~- ~re~~t,-~~. (~GlS~i~ li~l1V~2Q~I-to..~ 1 C~~a- / ~~~.~~~~~ {~Q~ ~ ~ Zd~~ Performance Wells Components - 16 ---- 32 -- - Failures Failure Rate --1- --- 3.12%__---- --~ Monday, February 25, 2008 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc / 7 FLi Àú \.J ç- DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 5 ¡l1u! J) r~ ÀANJ )... Permit to Drill 2022450 Well Name/No. PRUDHOE SAY UN AURO S-109 Operator SP EXPLORATION (ALASKA) INC API No. 50-029-23135-00-00 MD 11600 ./ TVD 6794 Completion Date 1/17/2003 /' Completion Status 1-01L Current Status 1-01L UIC N - ._-- __·o_______ - ~~------ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes - -- ---- ---- -- ------------------ DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, PWD, DEN, NEU, INC, USIT (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Logl Electr '---- Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments j --_._~ ---- ---- Rpt Directional Survey 0 11600 Open 2/3/2003 ~D Directional Survey 0 8446 Open 2/3/2003 PB1 ~·D Directional Survey ·0 11600 Open 2/3/2003 ; Rpt Directional Survey 0 8446 Open 2/3/2003 PB1 ~ .- Sonic 5 Col 3000 7620 Case 2/14/2003 U 5it lID C Pds 62105 I nd uction/Resistivity 25 1-5 108 11557 Open 5/30/2003 J Vision Resistivity - MD ~D C Pds .J.21 05 Induction/Resistivity 25 1-5 108 11557 Open 5/30/2003 Vision Resistivity - TVD (Log o nd uction/Resistivity 25 Blu 1-5 108 11557 Open 5/30/2003 Vision Resistivity - MD \.-LOg lLnduction/Resistivity 25 Blu 1-5 108 11557 Open 5/30/2003 Vision Resistivity - TVD ~ C Pds L9105 Neutron 25 1-5 108 11557 Open 5/30/2003 'VISION Density Neutron - I MD i 41105 ---.. ~D C Pds Neutron 25 1-5 108 11557 Open 5/30/2003 VISION Density Neutron - TVD Log (Neutron . ~5 Blu, 1-5 108 11557 Open 5/30/2003 VISION Density Neutron - MD ¡ It.og '-Néutron '25 Blu 1-5 108 11557 Open 5/30/2003 VISION Density Neutron- TVD ~D C Pds U 21 05 Density 25 1-5 108 11557 Open 5/30/2003 f VISION Density Neutron - MD yo C Pds '1'2105 Density 25 1-5 108 11557 Open 5/30/2003 VISION Density Neutron - TVD fLog l. Density 25 Blu 1-5 108 11557 Open 5/30/2003 VISION Density Neutron - MD L Log Density 25 Blu 1-5 108 11557 Open 5/30/2003 VISION Density Neutron - TVD -_.--- ---- DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Permit to Drill 2022450 Well Name/No. PRUDHOE SAY UN AURO S-109 Operator SP EXPLORATION (ALASKA) INC API No. 50-029-23135-00-00 MD 11600 TVD 6794 Completion Date 1/17/2003 Completion Status 1-01L Current Status 1-01L UIC N '~b-- - -- --- - 02105 108 11557 Open 5/30/2003 'VISION Service - MD C Pds See Notes 25 1-5 ~ C Pds Lr11 05 See Notes 25 1-5 108 11557 Open 5/30/2003 . VISION Service - TVD ~Og See Notes 25 Blu 1-5 108 11557 Open 5/30/2003 VISION Service - MD ~99 See Notes 25 Blu 1-5 108 11557 Open 5/30/2003 VISION Service - TVD 0'og ~oduction 25 Blu 7748 11430 Case 5/30/2003 Memory Production Profile - Memory GRlCCLfT emp/Press/Spin ~6 ~ C Asc ;;'2105 LIS Verification 108 11557 Open 5/30/2003 ¡ !ID- C Asc (121 06 LIS Verification 4 7820 8369 Open 5/30/2003 PB1 P C Pds ~06 Density 25 4 7820 8369 Open 5/30/2003 VISION Density Neutron - MD - PB1 LSD C Pds ct11 06 Density 25 4 7820 8369 Open 5/30/2003 VISION Density Neutron - . TVD - PB1 (1,.og Density 25 Blu 4 7820 8369 Open 5/30/2003 VISION Density Neutron - TVD - PB1 (jæg Density 25 Blu 4 7820 8369 Open 5/30/2003 VISION Density Neutron - MD - PB1 ~D C Pds 02106 Neutron 25 4 7820 8369 Open 5/30/2003 VISION Density Neutron - 'AD - PB1 <+-ED C Pds cJ.t1 06 Neutron 25 4 7820 8369 Open 5/30/2003 VISION Density Neutron - 'TVD - PB1 Log Neutron 25 Blu 4 7820 8369 Open 5/30/2003 VISION Density Neutron - MO - PB1 ~og Neutron 25 Blu 4 7820 8369 Open 5/30/2003 VISION Density Neutron - TVO - PB1 're C Pds 41106 I nduction/Resistivity 25 4 7820 8369 Open 5/30/2003 "VISION Resistivity - MO - PB1 ..--ED C Pds '"'t2106 Induction/Resistivity 25 4 7820 8369 Open 5/30/2003 I VISION Resistivity - TVO - PB1 l.Løg I nd uction/Resistivity 25 Blu 4 7820 8369 Open 5/30/2003 VISION Resistivity - MD - PB1 ~g I nd uction/Resistivity 25 Blu 4 uâ'20 8369 Open 5/30/2003 VISION Resistivity - TVO - PB1 :-ED . 0 Las 42276 Casing collar locator 7881 8208 1 0/6/2003 ~ -- - ------- DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Permit to Drill 2022450 Well Name/No. PRUDHOE SAY UN AURO S-109 Operator SP EXPLORATION (ALASKA)INC API No. 50-029-23135-00-00 MD 11600 TVD 6794 Completion Date 1/17/2003 Completion Status 1-01L Current Status 1-01L UIC N Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~. Daily History Received? A t!J1 N &N ~ Formation Tops Analysis Received? ~.. -- ---_._-"~._----- - - _.-- - - - -- -- --- --- ---~-- Comments: --------~ Compliance Reviewed By: ~ Date: to ~~\'~ - -" --------- ~' I ..)6 ~ I'· ) WELL LOG TRANSMITTAL c9Q9 ~¡YLJ5 ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7thStreet Suite # 700 Anchorage, Alaska 99501 RE : Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy I this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MVLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR COLOR Open Hole 1 Res. Eva!. CH 1 1 1 8-109 6-21-03 Mech. CH 1 jt)Ð7-0 Caliper Survey Signed: .~\~'-/~~ ~S\ ~~ -~/~ ti~r,l~ Date: OCT 0 6 (~ÜCj Print Name: ':~:;C;i1mbs;on PRoAcTivE DiAGNOSTic SERviCES, INC., PO Box 1 ~69 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com '~'~ "\--.-\.. C' \ '.. ~\~\'\0 Schlumbepger NO. 2865 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth éJoeJ -& ~{5 5/29/2003 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Well Job# Log Description Date BL Color 'S-109 PS1 23062 OH EDIT LWD, ARC, AND 01/09/03 S-109 PB1 23062 MD VISION RESISTIVITY 01/09/03 1 S-109 PB1 23062 TVD VISION RESISTIVITY 01/09/03 1 S-109 PB1 23062 MD DEN/NEUTRON 01/09/03 1 S-109 PB1 23062 TVD DEN/NEUTRON 01/09/03 1 S-109 23061 OH EDIT LWD, ARC, AND 01/12/03 S-109 23061 MD VISION RESISTIVITY 01/12/03 1 S-109 23061 TVD VISION RESISTIVITY 01/12/03 1 S-109 23061 MD DEN/NEUTRON 01/12/03 1 1J:P -d S-109 23061 TVD DEN/NEUTRON 01/12/03 1 S-109 23061 MD VISION SERVICE 01/12/03 1 S-109 23061 TVD VISION SERVICE 01/12/03 1 S-109 MEMORY PROD PROFILE 05/07/03 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 RECE!\ IE~D 900 E Benson Blvd. I V Anchorage AK 99508-4254 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth UA'( -; 0 2!1f\7 IVf. 0 { v V;') CD .~ 1 iBlÖ(P 1 JB. )Q~ /_' Received ~~~a\ ~~ ~~~'v\. Date Delivered: ÞJa3Ka O¡1 B\ n;;~ C«~~·2. C'::mm:~(m !'J!{¡ilCft(1fJ ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 03/11/03, 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4466' NSL, 4498' WEL, SEC. 35, T12N, R12E, UM At top of productive interval 43221 NSL, 958' WEL, SEC. 35, T12N, R12E, UM X = 622472, Y = 5980583 10. Well Number At total depth 275' NSL, 2431' EWL, SEC. 25, T12N, R12E, UM X = 625839, Y = 5981871 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 64.4' ADL 028257 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 12/31/2002 1/12/2003 1/17/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 11600 6794 FT 11600 6794 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, DEN, NEU, INC, USIT CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 109' 42" 29' 3030' 12-1/4" 26' 7820' 8-3/4" 76461 11470' 6-1/8" 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 5, 2003 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL 3/5/2003 4 TEST PERIOD 2,083 Flow Tubing Casing Pressure CALCULATED OIL-BBL Press. 25£ 24-HoUR RATE 23. CASING SIZE 34" X 20" 9-5/8" WT. PER FT. 91.5# 40# 26# 12.6# GRADE H-40 L-80 L-80 L-80 7" 4-1/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Section MD TVD 9406' - 11428' 6823' - 6824' MD Put on Production Classification of Service Well . ' " ·'''Iilor'¡i.~ o Service ,,' " ,,~,. ;'uor'~il':",,,, ",,!~m~.l : .' 1~':"'~"r1 '. "'':-~~';I;i:'~~ . - ~ " ~;i' :U' " '" ' 1"'.- ;':'''' ~", ",0"",1:",.""" ",( ~'\.:.,,""_f.t' .,' .":",0:.":":":"'/, ," ~:",:;;.,I.'. 7. Permit Number 202-245 8. API Number 50- 029-23135-00 9. Unit or Lease Name X = 618930, Y = 5980670 Prudhoe Bay Unit 5-109 11. Field and Pool Prudhoe Bay Field / Aurora Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2283' MD 1900' (Approx.) CEMENTING RECORD 260 sx Arctic Set (Approx.) 603 sx PF 'L', 229 sx Class 'G' 248 sx Litecrete, 92 sx Class 'G' 208 sx Class 'G' (Slotted Uner Uncemented) AMOUNT PULLED 25. TUBING RECORD DEPTH SET (MD) 7643' PACKER SET (MD) 7552' SIZE 4-1/2", 12.6#, L-80 TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 135 Bbls of Diesel GAs-McF 1,092 GAs-McF WATER-BBL 48 WATER-BBL CHOKE SIZE 1760 OIL GRAVITY-API (CORR) GAS-OIL RATIO 524 ?8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ,c~~-:c, ~.~, '\~. i;""' .~-\; ;'~.~~'~',' ,r. .~:~, - ¡': \_ 1_.....::;..--.: ~."7::'.\.:.: ~ No core samples were taken. Form 10-407 Rev. 07-01-80 , f' ", t.'.. .. " .' --....\ ' '·\;.1...,:. _ ..,,' '.:;.,.1' q ~ ,; \ - 3 '.I M 5 B F L I~-- (~- : ') I '::. Submit In Duplicate 29. ) ) ,\ 30. Geologic Markers Marker Name Ugnu Ugnu M Sandstones Schrader Bluff N Sandstones Schrader Bluff 0 Sandstones Base Schrader I Top Colville HRZ Kalubik Kuparuk C Kuparuk A Kuparuk A I Base Kuparuk C Kuparuk Cr / Base Kalubik Top Kalubik / Base HRZ 31. List of Attachments: Formation Tests Measured Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. True Vertical Depth 3897' 5268' 5502' 5630' 5954' 7530' 7802' 7815' 8034' 8416' 11473' 11494' 3597' 4787' 4986' 5097' 5381' 6613' 6733' 6738' 6794' 6804' 6818' 6814' Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~J ~ Title Technical Assistant Date 03 ·/1.. 0.3 S-109 202-245 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Rob Tirpack, 564-4166 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, 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 1. Status of Well Classification of Service Well 2. ~~~ of o~~a~:r 0 Suspended 0 AbandonedO·~_7;~; i ~.'J~TOO¡1" 7. Permit Number B E I . (AI k) , . ..... '- , V@!}ftSf>,. 202 245 P xp oration as a Inc. ;\ ~ ~'l'" - 3 Address .1.~X!~~..:_ [' 1 t:lJ ~:~ "~ 8. API Number . P.O. Box 196612, Anchorage, Alaska 99519-6612 i "-"-'j:iL::_,__ ~ l~,;,~~,.;;~~~ 50-029-23135-00 4. Location of well at surface ~,.,.. .-··,.-,_~._.'_'.i; 9. Unit or Lease Name 4466' NSL, 4498' WEL, SEC. 35, T12N, R12E, UM X = 618930, Y = 5980670 Prudhoe Bay Unit At top of productive interval 4322' NSL, 958' WEL, SEC. 35, T12N, R12E, UM X = 622472, Y = 5980583 10. Well Number At total depth 275' NSL, 2431' EWL, SEC. 25, T12N, R12E, UM X = 625839, Y = 5981871 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 64.4' ADL 028257 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 12/31/2002 ¡. 1/12/2003 I 1/17/2003 · 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 11600 6794 FT 11600 6794 FT 1m Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, DEN, NEU, INC, US IT CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 109' 42" 29' 3030' 12-1/4" 26' 7820' 8-3/4" 7646' 11470' 6-1/811 23. CASING SIZE WT. PER FT. 91.5# 40# 26# 12.6# 34" x 20" 9-5/8" 7" 4-1/211 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 8-109 11. Field and Pool Prudhoe Bay Field I Aurora Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2283' MD 1900' (Approx.) GRADE H-40 L-80 L-80 L-80 CEMENTING RECORD 260 sx Arctic Set (Approx.) 603 sx PF 'L', 229 sx Class 'G' 248 sx Litecrete 92 sx Class 'G' 208 sx Class 'G' (Slotted Uner Uncemented) AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/211 Slotted Section Flow Tubing Casing Pressure CALCULATED 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. MD TVD 9406' - 11428' 6823' - 6824' 27. Date First Production Not on Production Date of Test Hours Tested No core samples were taken. Form 1 0-407 Rev. 07-01-80 25. TUBING RECORD DEPTH SET (MD) 7643' PACKER SET (MD) 7552' SIZE 4-1/2", 12.6#, L-80 MD TVD 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 135 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR Oll-BBl TEST PERIOD GAs-McF CHOKE SIZE GAS-Oil RATIO WATER-BBl Oil -BBl WATER-BBl Oil GRAVITY-API (CORR) GAs-McF G r~ i"\ n rU4S B F L t-t8 ¿ 12m? Submit In Duplicate 29. ) ) 30. Geologic Markers Measured Depth Marker Name Ugnu Ugnu M Sandstones Schrader Bluff N Sandstones Schrader Bluff 0 Sandstones Base Schrader I Top Colville HRZ Kalubik Kuparuk C Kuparuk A Kuparuk A I Base Kuparuk C Kuparuk Cr / Base Kalubik Top Kalubik I Base HRZ 31. List of Attachments: Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 3897' 5268' 5502' 5630' 5954' 7530' 7802' 7815' 8034' 8416' 11473' 11494' 3597' 4787' 4986' 5097' 5381' 6613' 6733' 67381 6794' 6804' 6818' 6814' Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the fo~oin: is true and correct to the best of my knowledge Signed Terrie Hubble -"10 AM t ~ 1 ~ Title Technical Assistant Date ()~" (9"03 S-109 202-245 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Rob Tirpack, 564-4166 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, 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 Legal Name: Common Name: Test Date 1/4/2003 1/8/2003 LOT FIT 8-1 09 8-1 09 Test Type Test Depth (TMD) 3,030.0 (ft) 7,820.0 (ft) TestDepth tTVO) 2,849.0 (ft) 6,743.0 (ft) Surface.preS$lIre 730 (psi) 750 (psi) AMW 9.65 (ppg) 10.00 (ppg) L~af{OffR"èssure (~Hfn 2,158 (psi) 4,253 (psi) EMW 14.58 (ppg) 12.14 (ppg) -' ~ Printed: 1/20/2003 9:25:24 AM ) ) BP OperéJ.tions Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-109 S-1 09 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From -To Hours Task Code NPT Phase· 12/30/2002 21 :00 - 00:00 3.00 MOB P PRE 12/31/2002 00:00 - 03:00 3.00 MOB P PRE 03:00 - 07:00 4.00 BOPSUR P SURF 07:00 - 11 :00 4.00 DRILL P SURF 11 :00 - 14:00 3.00 DRILL P SURF 14:00 - 14:30 0.50 DRILL P SURF 14:30 - 16:00 1.50 DRILL P SURF 16:00 - 00:00 8.00 DRILL P SURF 1/1/2003 00:00 - 01 :00 1.00 DRILL P SURF 01 :00 - 01 :30 01 :30 - 09:00 0.50 DRILL P 7.50 DRILL P SURF SURF 09:00 - 09:30 0.50 DRILL P SURF 09:30 - 11 :00 1.50 DRILL P SURF 11:00-12:00 1.00 DRILL P SURF 12:00 - 12:30 0.50 DRILL P SURF 12:30 - 13:30 1.00 DRILL P SURF 13:30 - 00:00 10.50 DRILL P SURF 1/2/2003 00:00 - 00:30 0.50 DRILL P SURF 00:30 - 04:00 3.50 DRILL P SURF 04:00 - 06:30 2.50 DRILL P SURF 06:30 - 08:00 1.50 DRILL P SURF 08:00 - 09:00 1.00 DRILL P SURF 09:00 - 10:30 1.50 DRILL P SURF 10:30 - 11 :30 1.00 CASE P SURF Page 1 of 7 Start: 12/17/2002 Rig Release: 1/17/2003 Rig Number: 9ES Spud Date: 12/30/2002 End: 1/17/2003 Description· ofOperatiöns Rig down. Move pump I pit module and mechanic shop. Phase 2 weather conditions. Move rig from S-115 to S-1 09. Position pit module and mechanic shop. Rig up. Connect mud and utility lines, take on water. Rig accepted at 03:00 hrs 12/31/2002 Nipple up riser and flow line on 20" conductor. Load pipe shed with 4" drill pipe and strap same. Pick up 4" drill pipe and stand 35 stands in derrick. Pick up new 12 1/4" bit and directional drilling BHA. Spud well and drill to 171'. Maintain mud at 300 vis while drilling. Pull bit into conductor. Rig up Schlumberger E-line unit and gyro equipment. Run gyro survey at 171'. Drill 121/4" directional hole from 171' to 847'. Rotate and slide to control direction and angle. Run gyro surveys on E-line every 100'. Occasionally slow pump rate to 450 gpm to reduce mud losses over shakers. AST=2.48 ART=1.07 Drill 12 1/4" directional hole from 847' to 1033'. Rotate and slide to control direction and angle. Run gyro surveys on E-line every 100'. Occasionally slow pump rate to 450 gpm to reduce mud losses over shakers. Circulate at a reduced rate while changing shaker screens. Drill 12 1/4" directional hole from 1033' to 1655'. Rotate and slide to control direction and angle. Run gyro surveys on E-line every 1 00' to 1350'. AST=3.48 ART=2.38 Circulate bottoms up to clean hole prior to trip for bit. POH to change bit. No excessive drag on trip. Service top drive. Change bit and RIH with BHA. RIH with new bit. Work pipe through tight spots at 1370' and 1559'. Wash last stand to bottom as precaution. Drill 12 1/4" directional hole from 1655' to 3044' casing point. Rotate and slide to control direction and angle. Sudden reduction in ROP from 2150' to 2160'. Work pipe and fan bottom with bit. Resume drilling at previous ROP. AST=1.95 ART=3.68 Circulate bottoms up prior to wiper trip. POH. Intermitent drag and swabbing. Work pipe and back ream through tight spots at 2052', 1730' and 1469'. POH to 906'. RIH. String taking weight from 1710', wash through intermitent obstructions to 3044' Circulate and condition mud prior to POH to run 9 5/8" casing. POH to BHA. No swabbing or drag. Stand back HWDP, lay down BHA and bit. Make dummy run with 9 5/8" casing hanger on landing joint. '-r Printed: 1/20/2003 9:25:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/2/2003 1/3/2003 1/4/2003 115/2003 ) ), BP OperationsJ3ummary Report S-1 09 S-1 09 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Page 2c>f7 Start: 12/17/2002 Rig Release: 1/17/2003 Rig Number: 9ES Spud Date: 12/30/2002 End: 1/17/2003 From- To Hours Task Code NPT Phase 11:30-13:30 13:30 - 18:30 18:30 - 19:00 19:00 - 20:30 20:30 - 23:00 23:00 - 00:00 00:00 - 01 :00 01 :00 - 03:30 03:30 - 05:30 05:30 - 08:30 08:30 - 13:00 13:00 - 13:30 13:30 - 14:30 14:30 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 07:00 07:00 - 07:30 07:30 - 08:00 08:00 - 00:00 00:00 - 17:30 2.00 CASE P 5.00 CASE P SURF SURF 0.50 CEMT P 1.50 CEMT P SURF SURF 2.50 CEMT P SURF 1.00 CEMT P 1.00 CEMT P SURF SURF 2.50 CEMT P 2.00 DRILL P SURF INT1 3.00 BOPSURP 4.50 BOPSURP INT1 INT1 0.50 WHSUR P 1.00 DRILL P 9.00 DRILL P 0.50 DRILL P INT1 INT1 INT1 INT1 1.50 DRILL P INT1 0.50 DRILL P INT1 1.00 DRILL P 1.00 DRILL P 1.00 CASE P 2.00 DRILL P INT1 INT1 INT1 INT1 0.50 DRILL P 0.50 DRILL P 16.00 DRILL P INT1 INT1 INT1 17.50 DRILL P INT1 Description of Operations· Rig up to run 9 5/8" casing. Make up fill-up tool. Run 3 joints 9 5/8" 40# L-80 BTC-M casing, check floats. Install Tam port collar at 1029'. Wash through tight spot at 1670'. Run a total of 72 joints with shoe at 3030' and float collar at 2948'. Lay down fill up tool and make up cementing head and lines. Circulate and condition mud prior to cement job, lower YP and vis. PJSM with Halliburton cementers and all rig personel. Pump 10 bbl water, test lines to 3500 psi, pump 10 bbl water. Pump 75 bbl Alpha Spacer at 10.5 ppg. Mix and pump lead slurry of 446 bbl (600 sx) Permafrost "L" cement at 1 0.7 ppg with additives. Fllowed by tail slurry of 47 bbl (230 sx) Premium "G" cement at 15.8 ppg with additives. Displace with rig pumps at 10 BPM, full returns, reciprocate pipe, bump plug, 75 bbl cement return, floats held. Cement in place at 22:56 hrs 1/2/2003 Rig down casing running tools. Flush out flow line and riser. Rig down casing running tools. Flush out flow line and riser. Lay down casing landing joint. Nipple down surface riser and flow nipple. Install FMC 12" casing head with 11" 5M top flange and test to 1000 psi. Nipple up FMC 11" x 11" 5M Gen-5 tubing head. Nipple up 135/8" 5M BOP. Test BOP and associated equipment to 250 psi low and 4000 psi high. Annular preventor tested to 3500 psi high. Test witnessed by John Spaulding of AOGCC. Install 9 1/8" ID wear bushing. Service top drive, blocks and crown. Pick up 5700' of 4" drill pipe and stand in derrick. Pick up BHA #3 with 1.15 deg bent housing and 8 3/4" uphole reamer. Pick up BHA #3 with new PDC bit, 1.15 deg bent housing and 8 3/4" uphole reamer. RIH to 1100'. Shallow test MWD. Pressure test casing to 1000 psi for 10 minutes to confirm Tam Port Collar integrity. Slip and cut drilling line 65' RIH to 2800', pick P 4" drill pipe from shed. Pressure test casing to 3500 psi for 30 minutes. Drill cement plugs and float collar at 2947'. Drill shoe track cement and shoe at 3030'. Drill out rat hole and new hole to 3064'. Displace mud in hole with new 9.7 ppg LSND mud. Perform LOT. EMW 14.6 ppg. Drill 83/4" directional hole from 3064' to 6083'. Slide and rotate to control direction and angle. WOB 25K, RPM (TD) 80, GPM 580, PSI 3120. Back ream full stand on connections. Pump high vis sweeps every 200' drilled. AST=1.82 ART=7.96 Drill 83/4" directional hole from 6083' to 7669'. Slide and rotate to control direction and angle. Sliding 60' on every stand to build angle. WOB 25K, RPM (TD) 100, GPM 580, PSI 3120. Printed: 1/20/2003 9:25:36 AM ) ) BP Päge3 of 7 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-1 09 S-1 09 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/17/2002 Rig Release: 1/17/2003 Rig Number: 9ES Spud Date: 12/30/2002 End: 1/17/2003 Date From - To Hours Task Code NPT Phase Descri ptionof· Operations 1/5/2003 00:00 - 17:30 17.50 DRILL P INT1 Back ream full stand on connections. Pump high vis sweeps every 200' drilled. AST=7.17 ART=3.01 17:30 - 22:30 5.00 DRILL P INT1 Drill 83/4" directional hole from 7669' to 7830'. Drill 30' intervals circlating up samples while looking for top of Kuparuk formation. Slide and rotate to control direction and angle. WOB 25K, RPM (TD) 100, GPM 580, PSI 3120. Back ream full stand on connections. Pump high vis sweeps every 200' drilled. AST=1.68 ART=0.92 22:30 - 00:00 1.50 DRILL P INT1 Circulate and condition mud. Pump around 15 bbl sweep prior to wiper trip. 1/6/2003 00:00 - 00:30 0.50 DRILL P INT1 Circulate and condition mud. Pump around 15 bbl sweep prior to wiper trip. 00:30 - 03:00 2.50 DRILL P INT1 POH. Work pipe through intermitent tight spots from 7830' to 6990'. Pull to 9 5/8" casing shoe, monitor well. 03:00 - 03:30 0.50 DRILL P INT1 Service top drive and crown. 03:30 - 05:00 1.50 DRILL P INT1 RIH to 5244' fill pipe and break circulation. RIH and wash last stand to bottom. 05:00 - 07:30 2.50 DRILL P INT1 Circulate and condition mud, clean hole. 07:30 - 08:30 1.00 DRILL P INT1 POH to 5954' no excessive drag. 08:30 - 09:30 1.00 DRILL P INT1 Break circulateion and spot Steel Seal pill across Schrader formation. 09:30 - 11 :30 2.00 DRILL P INT1 POH to BHA. 11 :30 - 13:30 2.00 DRILL P INT1 Lay down BHA and bit, stand back HWDP. 13:30 - 14:30 1.00 CASE P INT1 Pull wear bushing. Flush BOP. 14:30 - 15:30 1.00 CASE P INT1 Change pipe rams to 7". Install test plug and test BOP door seals to 3500 psi. 15:30 - 17:30 2.00 CASE P INT1 Rig up to run 7" casing. Make dummy run with 7" casing hanger on landing joint. 17:30 - 23:30 6.00 CASE P INT1 Run 7" 26# L-80 BTC-M casing. Make up 7" shoe track and check floats. RIH to 3014',73 joints. Fill casing every joint. 23:30 - 00:00 0.50 CASE P INT1 Circulate 1 1/2 times bottoms up at 6 bpm. 1/7/2003 00:00 - 03:30 3.50 CASE P INT1 Run 7" 26# L-80 BTC-M casing to 5250'. Fill casing every joint, break circulation every 15 joints and circulate every 25 joints run. 03:30 - 04:00 0.50 CASE P INT1 Circulate bottoms up at 5250' with 6 bpm. 04:00 - 08:30 4.50 CASE P INT1 Run 7" 26# L-80 BTC-M casing to 7820". Fill casing every joint, break circulation every 15 joints and circulate every 25 joints run, wash last joint to bottom. Total joints run 189. 08:30 - 09:00 0.50 CASE P INT1 Make up landing joint, lay down fill up tool, make up cementing head and lines. 09:00 - 11 :00 2.00 CEMT P INT1 Circulate and condition mud. PJSM with cementers and rig crew. 11 :00 - 13:30 2.50 CEMT P INT1 Pump 5 bbl water, test lines to 4000 psi. Pump 40 bbl weighted Alpha Spacer. Mix and pump lead slurry of 131 bbl (252 sx) Tuned Lite at 12 ppg with additives. Mix and pump tail slurry of 19 bbl (90 sx) Premium Cement at 15.8 ppg with additives. Displace with rig pumps and bump plug. Cement in place 13:02 13:30 -14:30 1.00 CEMT P INT1 Lay down landing joint. Rig down casing running equipment. Printed: 1/20/2003 9:25:36 AM ) ) BP Page 4 of7 Operations SU01mary·Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-1 09 8-109 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/17/2002 Rig Release: 1/17/2003 Rig Number: 9ES Spud Date: 12/30/2002 End: 1/17/2003 Date From - To HoUrs Task Code NPT Phase Description of Operations 1/7/2003 14:30 - 15:30 1.00 WHSUR P INT1 Install FMC 7" casing hanger pack off, run in lock down screws and test to 5000 psi. 15:30 - 17:30 2.00 BOPSURP INT1 Flush BOP, set test plug. Change top rams from 7" to variable rams. Rig up lines to test. 17:30 - 20:30 3.00 BOPSURP INT1 Test BOP and associated equipment to 250 psi low and 4000 psi high. Test annular to 250 psi low and 3500 psi high. Test wittness waived by John Spaulding of AOGCC. 20:30 - 21 :00 0.50 BOPSUR P INT1 Rig down test lines. Pull test plug and install wear bushing. 21 :00 - 21 :30 0.50 DRILL P PROD1 Bring BHA to rig floor. 21 :30 - 23:00 1.50 DRILL P PROD1 Slip and cut drilling line 58'. Inspect brakes. SIMOPS: While slip and cut drilling line pumped 73 bbl1 0.1 ppg drilling mud down 7" x 9 5/8" annulus. EMW=13.5 ppg. Freeze protect annulus with 65 bbl diesel at 90 deg F. 23:00 - 00:00 1.00 DRILL P PROD1 Safety stand down with rig crew and third party contractors. Discussed the importance of heightened safety awareness, weather conditions, communication and risk mitigation. 1/8/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Safety stand down with rig crew and third party contractors. Discussed the importance of heightened safety awareness, weather conditions, communication and risk mitigation. 01 :00 - 02:00 1.00 DRILL P PROD1 Service top drive and crown. 02:00 - 05:00 3.00 DRILL P PROD1 Pick up BHA, load nuclear sources. Shallow test MWD. 05:00 - 08:30 3.50 DRILL P PROD1 RIH with new bit and drilling BHA to 7600'. 08:30 - 09:30 1.00 CASE P PROD1 Circulate and fill pipe. Test casing to 4000 psi for 30 minutes. 09:30 - 11 :00 1.50 DRILL P PROD1 Tag up cement plugs at 7715'. Drill cement plugs and cement, drill float collar at 7736', cement in shoe track and float shoe at 7820' and clean out rat hole to 7830'. 11 : 00 - 11: 30 0.50 DRILL P PROD1 Drill new hole to 7851'. Slide to control angle and direction. 11:30-12:30 1.00 DRILL P PROD1 Displace mud in hole to new 10.0 ppg Baradril-N mud. 12:30 -13:00 0.50 DRILL P PROD1 Perform FIT with 730 psi EMW= 12.1 ppg. 13:00 - 22:30 9.50 DRILL P PROD1 Drill 6 1/8" directional hole from 7851' to 8141'. Slide and rotate to control direction and angle. WOB 10K, RPM (TO) 60, GPM 300, PSI 2765. Pump high vis sweeps periodically. Difficulty sliding. AST=3.8 ART=1.35 22:30 - 00:00 1.50 DRILL P PROD1 POH 2 stands to 7" casing shoe. Circulate around 46 bbl EP Mud lube pill. RIH and wash last stand to bottom. 1/9/2003 00:00 - 11 :30 11.50 DRILL P PROD1 Drill 6 1/8" directional hole from 8141' to 8446'. Slide and rotate to control direction and angle. WOB 12K, RPM (TO) 60, GPM 300, PSI 2568. Pump 10 bbl high vis sweeps periodically. Difficulty sliding. AST=5.4 ART=1.2 11 :30 - 16:00 4.50 DRILL P PROD1 POH to 8300'. Execute a low side open hole side track. Drill from 8300' to 8325'. WOB 10K, RPM (TO) 60, GPM 300, PSI 2565. Very low ROP. AST=1.95 ART=1.57 16:00 - 16:30 0.50 DRILL P PROD1 Circulate bottoms up. 16:30 - 20:00 3.50 DRILL P PROD1 POH to BHA. PJSM prior to removing source. 20:00 - 22:30 2.50 DRILL P PROD1 Stand back HWDP and jars. Remove source, break put bit, down load MWD. 22:30 - 00:00 1.50 DRILL P PROD1 Change bit amd mud motor. Make up LWD and orient, load Printed: 1/20/2003 9:25:36 AM '} ) BP Operations Summary Rèport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-1 09 S-1 09 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/17/2002 Rig Release: 1/17/2003 Rig Number: 9ES Spud Date: 12/30/2002 End: 1/17/2003 Date From -To Hours Task Code NPT Phase . Description of Operations 1/9/2003 22:30 - 00:00 1.50 DRILL P PROD1 source. 1/10/2003 00:00 - 01 :30 1.50 DRILL P PROD1 Make up LWD and orient, load radioactive source. Shallow test MWD. 01 :30 - 04:00 2.50 DRILL P PROD1 RIH to 7" casing shoe. Fill pipe at 3513' and break circulation at shoe. 04:00 - 04:30 0.50 DRILL P PROD1 Service top drive. 04:30 - 05:00 0.50 DRILL P PROD1 RIH. Wash last stand down as precaution, no fill. 05:00 - 00:00 19.00 DRILL P PROD1 Drill 6 1/8" directional hole from 8325' to 8949'. Slide and rotate to control direction and angle. WOB 10K, RPM (TO) 60, GPM 300, PSI 2650. Pump 10 bbl high vis sweeps periodically. AST=9.54 ART=2.7 1/11/2003 00:00 - 00:00 24.00 DRILL P PROD1 Drill 6 1/8" directional hole from 8949' to 10395'. Slide and rotate to control direction and angle. WOB 10K, RPM (TO) 60, GPM 300, PSI 2650. Pump 10 bbl high vis sweeps periodically. AST=11.57 ART=4.13 1/12/2003 00:00 - 17:30 17.50 DRILL P PROD1 Drill 6 1/8" directional hole from 8949' to 11600' TO. Slide and rotate to control direction and angle. WOB 15K, RPM (TO) 60, GPM 300, PSI 3430. Pump 10 bbl high vis sweeps periodically. AST=5.58 ART=6.42 17:30 - 19:00 1.50 DRILL P PROD1 Circulate and condition mud. Pump around high vis sweep to clean hole. 19:00 - 00:00 5.00 EVAL P PROD1 MAD Pass open hole section. POH at 400 FPH, rotating at 55 RPM, pump at 245 GPM. No excessive torque or drag. 1/13/2003 00:00 - 10:30 10.50 EVAL P PROD1 MAD Pass open hole section. POH at 400 FPH, rotating at 55 RPM, pump at 245 GPM. No excessive torque or drag. 10:30 - 11 :30 1.00 DRILL P PROD1 Circulate bottoms up. 11 :30 - 12:30 1.00 DRILL P PROD1 Service top drive. 12:30 - 13:30 1.00 DRILL P PROD1 Slip and cut drilling line 60'. Adjust and inspect drawworks brakes. 13:30 - 15:30 2.00 DRILL P PROD1 RIH from casing shoe to 9700', fill pipe and continue RIH to 11490'. Taking weight, work pipe down to 11522' no further progress. 15:30 - 17:00 1.50 DRILL P PROD1 Connect top drive and wash down to 11533'. Hole packing off intermittently, work pipe back up to 11510'. Work pipe & circ from 11510' and above-OK. 17:00 - 20:30 3.50 DRILL P PROD1 Circulate bottoms up. Pump around high vis sweep. Spot 146 bbl new Baradril n mud in open hole. 20:30 - 22:30 2.00 DRILL P PROD1 POH to 7" casing shoe. No excessive drag. 22:30 - 00:00 1.50 DRILL P PROD1 Drop dart to open circulating sub. Circulate casing clean at 420 gpm. 1/14/2003 00:00 - 02:30 2.50 DRILL P PROD1 Continue POH with DP. 02:30 - 05:00 2.50 DRILL P PROD1 Flush BHA. Download source. LD BHA. Clear floor. 05:00 - 06:00 1.00 CASE P COMP RU to run 4 1/2" slotted/solid liner. 06:00 - 06:15 0.25 CASE P COMP Hold PJSM with crew & service company. 06:15 - 11 :00 4.75 CASE P COMP Run 51 jts 4.5" slotted liner followed by 40 jts 4.5" solid liner plus ECP and associated tools. 11 :00 - 14:30 3.50 CASE P COMP RU to run 2 7/8" inner string. PU ECP inflation tool and stinger. Printed: 1/20/2003 9:25:36 AM ') ), Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date S-1 09 S-1 09 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES 1/14/2003 From - To Hours Task CÖdë NPT Phase 11 :00 - 14:30 3.50 CASE P COMP 14:30 - 15:30 1.00 CASE P COMP 15:30 - 18:30 3.00 CASE P COMP 18:30 - 19:00 0.50 CASE P COMP 19:00 - 19:30 0.50 CASE P COMP 19:30 - 22:00 2.50 CASE P COMP 22:00 - 23:00 1.00 CASE P COMP 23:00 - 00:00 1.00 CASE P COMP 00:00 - 01 :00 1.00 CASE P COMP 01 :00 - 02:00 1.00 CASE P COMP 1/15/2003 02:00 - 02:30 0.50 CEMT P COMP 02:30 - 03:30 1.00 CEMT P COMP 03:30 - 04:30 1.00 CEMT P COMP 04:30 - 05:00 0.50 CEMT P COMP 05:00 - 05:30 0.50 CEMT P COMP 05:30 - 07:00 1.50 CLEAN P COMP 07:00 - 15:00 8.00 CASE P COMP 15:00 - 15:30 0.50 CASE P COMP 15:30 - 19:00 3.50 BOPSUR P COMP 19:00 - 23:00 4.00 EVAL P COMP 23:00 - 00:00 1.00 EVAL P COMP 1/16/2003 00:00 - 05:00 5.00 EVAL P COMP 05:00 - 06:00 1.00 CASE P COMP 06:00 - 08:00 2.00 CASE IP COMP 08:00 - 09:00 1.00 RUNCOI\1P COMP 09:00 - 10:00 I 1.00 RUNCOf\,p COMP 10:00 - 21 :00 11.00 RUNCONP COMP I I Start: 12/17/2002 Rig Release: 1/17/2003 Rig Number: 9ES Spud Date: 12/30/2002 End: 1/17/2003 DescriptiOn ofOperatiöns PU & run 2 7/8" inner string to ECP. MU 7" x 5" Baker Flex-Lock hanger and ZXP L TP. RD casing tools. PU 1 stand HWDP. Circ liner - OK. 3 BPM @ 340 psi. RIH with liner on 4" DP to shoe at 7820'. Run 2 min slips»slips to minimise running mud over top of DP. MU Baker circ head prior to going in to open hole. Circ at 7" shoe to verify DP & work string clear. 3 BPM @ 565 psi. 150K up. 118K dn. Continue RIH to 11,470'. No Problems, Hole in good shape. Displacement correct. PU = 170K, DN = 11 OK. Establish circulation w/ Rig pumps - 3 BPM @ 810 psi. Pumped 90 Bbls. PJSM wi all personnel. Drop two stage plug. Switch to HOWCO pumps & test lines to 5000 psi. Pump down plug. Chase Plug wi 89 Bbls Mud wi HOWCO - No Bump. Break out swivel- plug above. N/U TIW below swivel and pump plug to catcher. Set Hanger & Hang wi 20K. Pressure to 3000 psi to release "HR" running tool. Pickup & close PPIT. Test to 1000 psi. Pickup 26' to "ECP" . Inflate "ECP". P/U 23' to HMCV. Pressure to 2000 psi to open HMCV. Circulate 50 Bbls Mud through HMCV @ 5 BPM - 1300 psi. Pump 5 Bbls, 3% KCL Water, 25 bbls - 11 ppg. Alpha spacer, followed by 43 Bbls, 15.8 ppg, Super CBL Cement Slurry. Displace w/81 Bbls Mud. P/U to close HMCV. Pressure test to 3250 psi. Release reverse sleeve in RPC. Set "ZXP" liner Top Packer. P/U to tool Jt., close Annular & reverse 5 Bbls. Mud. Pressure DP to 4500 psi to shear open drain sub. Circulate @ 300 GPM - 300 psi long way. 4 Bbls Cement to surface. Set down on "ZXP" Pkr & test Liner top to 2500 psi for 10 Minutes. Break out & LID Cement Head. Displace wellbore w/1 0 ppg. filtered NaCI brine. POH LID 4" DP & 2 7/8" Inner String. Load out all 2 7/8" Baker Equipment. Wash out Stack Pull Wear Bushing. Install Test Plug & Test BOPE to 250/4000 psi, Annular to 250/3500 psi. Lower Top Drive valve failed. Change out valve - Retest - OK. Witness of Test waived by Chuck Scheve, AOGCC. PJSM wi SWS and all Hands. R/U & RIH wi 6.025" Gauge ring and WLJB to 7640' WL depth. Retrieved 2 Gal debris to include some rubber. Make second run - very little and very small debris. LID Gauge Ring & WLJB. M/U USIT Tool & RIH. Log USIT in 7" Casing from 7620' . Top of good Cement @ 3150'. POH & RID SWS. RIH wI 41 Stands of 4" DP from Derrick. POH Laying Down DP. Pull Wear Bushing, Flush stack, M/U Hanger and Landing Jt. - Make Dummy Run. Change Bails & R/U to run Tubing. Run 4.5" Completion Tubing String as per Program. Total 181 Printed: 1/20/2003 925:36 AM ) ) BP Page Tof 7 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-109 S-1 09 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From - To Hours Task Code NPT Phase 1/16/2003 10:00 - 21 :00 11.00 RUNCOIVP CaMP 21 :00 - 23:30 2.50 CHEM P CaMP 1/17/2003 23:30 - 00:00 00:00 - 00:30 00:30 - 02:30 CaMP CaMP CaMP 0.50 DHEQP P 0.50 WHSUR P 2.00 RUNCOIVP 02:30 - 05:00 2.50 BOPSUR P CaMP 05:00 - 07:00 2.00 WHSUR P CaMP 07:00 - 08:00 1.00 WHSUR P CaMP 08:00 - 10:30 2.50 RUNCOIVP CaMP 10:30 - 12:00 1.50 WHSUR P CaMP Start: 12/17/2002 Rig Release: 1/17/2003 Rig Number: 9ES Spud Date: 12/30/2002 End: 1/17/2003 Description of Operations Jts. Space out WLEG into Tie Back Receptacle. M/U Hanger & Landing Jt. Double Check Space Out. Reverse Circulate, Displacing Wellbore fluid w/ Filtered, 10.0 ppg. NaCI 1 NaBr Brine, spotting Corrosion Inhibited Brine In Annulus. Drop Ball 1 Rod Assembly & Land Hanger in Wellhead. Torque lock down screws on tubing hanger. Pressure tubing to 4200 psi for 30 min to set packer and test tubing - OK. Bleed tubing to 2500 psi and pressure up on annulus to 4000 psi for 30 min test - OK. Bleed off pressure on both sides. Re-pressure annulus to 3000 psi to shear open DCK valve - OK. Pull landing jt. Install TWC & test from below to 2800 psi. ND BOPE & set back same. NU tubing head adaptor & tree. Test to 5000 psi - OK. RU lubricator & pull TWC. RU Little Red and pump 135 bbl heated diesel to IA. 2.5 bpm @ 1500 psi. Shut down and allow diesel to U-tube from annulus to tubing and equalise. Final tubing pressure 350 psi. Set BPV in tubing hanger with lubricator & test to 1000 psi - OK. Secure well. RELEASE RIG FROM S-109 AT 12:00 HRS ON 1/17/2003. Printed: 1/20/2003 9:25:36 AM SCHLUMBERGER Drilling & Measurements Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Aurora Well. . . . . . . . . . . . . . . . . . . . .: S-109 API number. .. ..... .......: 50-029-23135-00 Engineer.................: E. Roux RIG: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 35.49 ft KB above permanent.......: N/A Top Drive Used DF above permanent.......: 64.10 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)...... ..: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: N 70.355842330 Departure (+E/W-)........: W 149.03414107 Azimuth from rotary table to target: 81.70 degrees [(c)2003 Drilling & Measurements IDEAL ID6_1C_10J 13-Jan-2003 04:34:03 Spud date................: Last survey date...... ...: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 8 31-Dec-02 13-Jan-03 208 0.00 ft 11600.00 ft -"- ----- Geomagnetic data ---------------------- Magnetic model. ....... ...: BGGM version 2001 Magnetic date..... ..... ..: 31-Dec-2002 Magnetic field strength..: 1150.02 HCNT Magnetic dec (+E/W-).....: 25.97 degrees Magnetic dip... ..........: 80.81 degrees ----- MWD survey Reference Reference G. ... ...... ....: Reference H.... .... ......: Reference Dip............: Tolerance of G. ..........: Tolerance of H.... ..... ..: Tolerance of Dip... ... ...: Criteria --------- 1002.68 mGal 1150.02 HCNT 80.82 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees '~ ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.84 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.84 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........: No degree: 0.00 fI t Drilling & Measurements SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 -------- -------- 1 2 3 4 5 0.00 77.00 170.00 265.00 350.00 449.00 550.00 650.00 726.00 825.00 925.00 1025.00 1125.00 1195.00 1315.75 1408.67 1498.59 1592.39 1685.62 1778.58 1871.86 1964.47 2058.45 2153.60 2245.19 2339.43 2432.84 2524.85 2618.26 2712.50 ------ ------ Incl angle (deg) 13-Jan-2003 04:34:03 ------- ------ -------- -------- ---------------- --------------- ------- ------ -------- -------- ---------------- --------------- Page Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Az im (deg) ------ ------- ------ -------- -------- ---------------- --------------- ------ ------- ------ -------- -------- ---------------- --------------- 0.00 0.37 0.18 1.95 3.87 5.57 5.61 6.45 7.71 9.59 11.35 12.97 15.59 17.17 19.19 18.78 18.50 17.74 18.89 19.66 20.37 19.88 21.76 23.24 25.16 27.30 29.66 29.83 30.87 30.79 0.00 315.63 65.86 103.28 102.62 101.19 101.50 97.94 98.46 98.70 90.93 94.90 90.42 91.10 91.58 91.28 91.03 90.62 91.12 88.85 88.94 88.88 88.38 90.14 90.65 89.17 87.41 87.15 87.71 87.48 0.00 77.00 93.00 95.00 85.00 99.00 101.00 100.00 76.00 99.00 100.00 100.00 100.00 70.00 120.75 92.92 89.92 93.80 93.23 92.96 93.28 92.61 93.98 95.15 91.59 94.24 93.41 92 01 93.41 94.24 0.00 77.00 170.00 264.98 349.87 448.53 549.05 648.49 723.91 821.78 920.12 1017.87 1114.78 1181.93 1296.65 1384.51 1469.72 1558.87 1647.37 1735.12 1822.77 1909.72 1997.56 2085.47 2169.00 2253.54 2335.64 2415.52 2496.13 2577.06 0.00 -0.15 -0.18 1.46 5.49 13.14 22.40 32.40 41.38 55.62 73.30 93.94 118.16 137.65 174.79 204.58 232.93 261.73 290.65 321.02 352.69 384.30 417.46 453.55 490.66 531.88 576.13 621.56 668.52 716.56 0.00 0.18 0.45 0.14 -0.82 -2.48 -4.42 -6.17 -7.51 -9.73 -11.15 -12.27 -13.33 -13.59 -14.48 -15.24 -15.82 -16.24 -16.69 -16.67 -16.05 -15.45 -14.64 -14.19 -14.45 -14.37 -13.01 -10.85 -8.73 -6.71 0.00 -0.17 -0.25 1.46 5.67 13.64 23.29 33.64 42.91 57.63 75.71 96.73 121.35 141.09 178.75 208.97 237.70 266.87 296.17 326.85 358.77 390.63 424.02 460.42 497.96 539.61 584.12 629.72 676.87 725.13 0.00 0.25 0.52 1.47 5.72 13.86 23.70 34.20 43.56 58.45 76.52 97.50 122.08 141.74 179.34 209.52 238.23 267.37 296.64 327.27 359.13 390.93 424.27 460.64 498.17 539.80 584.27 629.82 676.93 725.16 0.00 315.63 331.01 84.45 98.21 100.30 100.74 100.39 99.92 99.58 98.38 97.23 96 ..27 95.50 94.63 94.17 93.81 93.48 93.23 92.92 92.56 92.26 91.98 91.77 91.66 91.53 91.28 90.99 90.74 90.53 2 of 8 DLS (deg/ 100f) 0.00 0.48 0.50 1.91 2.26 1.72 0.05 0.92 1.66 1.90 2.25 1.82 2.84 2.27 1.68 0.45 0.32 0.82 1.24 1.16 0.76 0.53 2.01 1.71 2.11 2.37 2.68 0.23 1.15 0.15 ------ ----- ------ Srvy tool type Tool qual type ------ ------ TIP Gyro Gyro Gyro Gyro ~J Gyro Gyro Gyro Gyro Gyro Gyro Gyro Gyro Gyro MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA -- MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA Drilling & Measurements SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) ------ ------ Incl angle (deg) ------- ------- Azimuth angle (deg) 13-Jan-2003 04:34:03 ------ -------- -------- ---------------- ------ -------- -------- ---------------- Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) --------------- --------------- Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 2805.35 2898.76 2984.54 3030.96 3125.55 3218.25 3310.73 3404.25 3497.73 3590.53 3683.68 3776.79 3870.20 3963.46 4056.89 4149.50 4242.84 4335.30 4427.93 4520.75 4614.52 4708.76 4802.23 4894.58 4987.70 5079.93 5173.57 5267.45 5360.61 5452.16 31.77 31.40 31.14 30.52 30.48 30.66 30.77 30.67 30.26 30.31 30.27 29.47 28.88 28.85 28.22 28.39 28.06 28.00 27.85 29.62 30.09 29.40 29.16 30.47 32.04 32.23 32.51 32.68 33.06 31.36 86.60 86.70 86.57 86.27 86.38 86.16 85.93 88.38 88.50 87.54 87.05 89.82 89.14 88.86 90.92 90.50 89.66 89.08 92.74 93.47 93.59 93.48 92.98 92.35 92.91 92.32 91.67 91.00 91.10 90.80 92.85 93.41 85.78 46.42 94.59 92.70 92.48 93.52 93.48 92.80 93.15 93.11 93.41 93.26 93.43 92.61 93.34 92.46 92.63 92.82 93.77 94.24 93.47 92.35 93.12 92.23 93.64 93.88 93.16 91.55 2656.41 2735.98 2809.30 2849.16 2930.66 3010.48 3089.98 3170.38 3250.96 3331.09 3411.53 3492.27 3573.83 3655.50 3737.59 3819.12 3901.37 3982.98 4064.83 4146.22 4227.54 4309.36 4390.89 4471.02 4550.62 4628.72 4707.81 4786.90 4865.15 4942.61 764.56 813.31 857.67 881.37 929.23 976.22 1023.32 1070.87 1117.94 1164.45 1211.21 1257.25 1302.37 1347.02 1391.20 1434.57 1478.24 1521.30 1564.10 1607.84 1653.53 1699.29 1744.08 1789.16 1836.59 1884.76 1934.09 1983.95 2033.84 2082.00 -4.21 -1.35 1.26 2.74 5.82 8.89 12.15 14.52 15.81 17.43 19.64 20.92 21.33 22.12 22.21 21.67 21.61 22.08 21.40 18.97 16.10 13.22 10.64 8.51 6.29 4.05 2.31 1.13 0.20 -0.61 773.27 822.11 866.56 890.30 938.21 985.26 1032.38 1080.09 1127.47 1174.24 1221.17 1267.51 1313.04 1358.06 1402.68 1446.59 1490.73 1534.18 1577.53 1622.09 1668.68 1715.35 1760.99 1806.85 1855.12 1904.12 1954.23 2004.78 2055.34 2104.13 773.28 822.11 866.56 890.31 938.23 985.30 1032.45 1080.19 1127.58 1174.37 1221.32 1267.68 1313.22 1358.24 1402.86 1446.75 1490.89 1534.34 1577.68 1622.20 1668.76 1715.40 1761.02 1806.87 1855.13 1904.13 1954.23 2004.78 2055.34 2104.13 90.31 90.09 89.92 89.82 89.64 89.48 89.33 89.23 89.20 89.15 89.08 89.05 89.07 89.07 89.09 89.14 89.17 89.18 89.22 89.33 89.45 89.56 89.65 89.73 89.81 89.88 89.93 89.97 89.99 90.02 DLS (deg/ 100f) 1.16 0.40 0.31 1.38 0.07 0.23 0.17 1.34 0.44 0.52 0.27 1.71 0.72 0.15 1.25 0.28 0.55 0.30 1.86 1.94 0.51 0.73 0.37 1.46 1.71 0.40 0.48 0.42 0.41 1.87 Page 3 of 8 ------ ----- ------ Srvy tool type Tool qual type ------ ------ MWD IFR_MSA MWD_IFR_MSA MWD_IFR_MSA Interpolated MWD_IFR_MSA ,-" MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA "-" MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA Drilling & Measurements SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth ( ft) 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 -------- -------- 5544.57 5638.06 5730.76 5824.05 5918.28 6013.07 6106.73 6200.27 6293.77 6386.86 6480.48 6574.24 6667.36 6760.54 6853.79 6947.19 7039.47 7132.00 7224.51 7317.65 81 82 83 84 85 7410.67 7504.34 7597.32 7629.92 7660.49 86 87 88 89 90 7690.55 7723.59 7760.87 7870.48 7900.45 ------ ------ Incl angle (deg) ------ ------ 29.16 29.00 28.94 28.41 29.18 29.28 28.75 29.01 30.05 29.85 29.24 30.56 33.63 36.27 36.28 36.67 38.96 42.03 44.93 51.57 57.19 61.14 63.08 63.66 63.33 63.33 63.83 64.00 71.13 73.97 13-Jan-2003 04:34:03 ------- ------ -------- -------- ---------------- ------- ------ -------- -------- ---------------- Azimuth angle (deg) ------- ------- 91.74 92.91 91.55 90.61 92.36 92.69 92.50 94.62 95.18 94.61 94.64 95.02 96.73 96.55 94.28 90.57 89.72 90.96 93.69 97.07 100.13 101.23 101.70 101.54 101.09 101.48 101.34 101.89 108.81 109.00 Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) ------ -------- -------- ---------------- ------ -------- -------- ---------------- 92.41 93.49 92.70 93.29 94.23 94.79 93.66 93.54 93.50 93.09 93.62 93.76 93.12 93.18 93.25 93.40 92.28 92.53 92.51 93.14 93.02 93.67 92.98 32.60 30.57 30.06 33.04 37.28 109.61 29.97 5022.42 5104.13 5185.23 5267.08 5349.66 5432.38 5514.28 5596.19 5677.54 5758.20 5839.65 5920.93 5999.81 6076.17 6151.35 6226.47 6299.36 6369.72 6436.85 6498.84 6553.01 6601.01 6644.50 6659.11 6672.76 6686.25 6700.95 6717.34 6759.19 6768.18 2127.92 2172.58 2216.72 2260.88 2305.60 2351.06 2395.67 2439.88 2484.75 2529.99 2574.99 2620.50 2668.45 2720.03 2773.62 2828.15 2884.11 2943.50 3006.04 3073.48 3145.76 3221.80 3299.13 3326.53 3352.30 3377.61 3405.46 3436.94 3529.55 3554.98 -1.63 -3.47 -5.22 -6.07 -7.25 -9.29 -11.35 -14.16 -18.10 -22.06 -25.78 -29.72 -34.82 -40.99 -46.19 -48.53 -48.66 -49.04 -51.66 -58.28 -69.65 -84.57 -100.90 -106.77 -112.14 -117.40 -123.25 -129.99 -156.93 -166.19 2150.68 2196.08 2240.94 2285.70 2331.06 2377.31 2422.69 2467.77 2513.69 2559.99 2606.01 2652.58 2701.78 2754.80 2809.71 2865.17 2921.74 2981.82 3045.40 3114.51 3189.22 3268.24 3348.77 3377.32 3404.14 3430.49 3459.49 3492.29 3589.81 3616.85 --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 2150.68 2196.08 2240.95 2285.70 2331.08 2377.32 2422.72 2467.81 2513.75 2560.09 2606.13 2652.74 2702.00 2755.10 2810.09 2865.58 2922.14 2982.22 3045.84 3115.06 3189.98 3269.33 3350.29 3379.01 3405.99 3432.49 3461.69 3494.71 3593.23 3620.67 90.04 90.09 90.13 90.15 90.18 90.22 90.27 90.33 90.41 90.49 90.57 90.64 90.74 90.85 90.94 90.97 90.95 90.94 90.97 91.07 91.25 91.48 91.73 91.81 91.89 91.96 92.04 92.13 92.50 92.63 DLS (deg/ 100f) 2.44 0.63 0.71 0.75 1.21 0.20 0.57 1.13 1.15 0.37 0.65 1.42 3.44 2.84 1.44 2.40 2.54 3.43 3.73 7.62 6.61 4.34 2.13 1.83 1.70 1.16 1.56 1.40 8.73 9.50 Page 4 of 8 ------ ------ Srvy tool type Tool qual type ----- ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ~--;:,. MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA '-' MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA Drilling & Measurements SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 -------- -------- 7931.45 7963.02 7995.02 8026.01 8057.55 8088.58 8122.03 8151.56 8183.00 8214.64 8244.48 8273.17 8306.31 8337.68 8368.79 8399.57 8429.81 8460.50 8492.01 8522.22 8555.20 8585.86 8616.51 8648.02 8680.46 8710.11 8741.39 8772.67 8805.40 8836.19 ------ ------ Incl angle (deg) ------ ------ 76.70 79.75 80.00 81.56 83.73 83.91 85.77 88.89 90.23 90.13 89.89 91.02 90.54 90.13 90.23 89.99 90.37 90.23 90.16 90.58 88.83 87.73 87.21 86.70 85.32 86.87 90.37 92.43 90.61 89.14 ------- ------- Azimuth angle (deg) ------ ------ Course length (ft) 13-Jan-2003 04:34:03 -------- -------- ---------------- -------- -------- ---------------- TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) --------------- --------------- Total displ (ft) At Azim (deg) ------- ------ -------- -------- ---------------- --------------- ------- ------ -------- -------- ---------------- --------------- 108.73 105.93 107.57 108.17 106.68 107.10 105.61 105.12 105.44 104.36 104.74 105.34 100.73 101.48 99.01 97.49 94.68 92.85 89.85 85.86 83.51 82.68 82.16 81.13 80.30 81.58 82.42 80.71 76.38 75.24 31.00 31.57 32.00 30.99 31.54 31.03 33.45 29.53 31.44 31.64 29.84 28.69 33.14 31.37 31.11 30.78 30.24 30.69 31.51 30.21 32.98 30.66 30.65 31.51 32.44 29.65 31.28 31.28 32.73 30.79 6776.02 6782.47 6788.09 6793.06 6797.10 6800.44 6803.45 6804.82 6805.06 6804.96 6804.96 6804.73 6804.28 6804.09 6804.00 6803.94 6803.84 6803.68 6803.57 6803.38 6803.55 6804.47 6805.82 6807.50 6809.75 6811.77 6812.53 6811.76 6810.89 6810.96 3581.66 3609.52 3638.05 3665.51 3693.69 3721.60 3751.88 3778.89 3807.70 3836.78 3864.28 3890.62 3921.48 3951.07 3980.56 4010.07 4039.35 4069.36 4100.42 4130.45 4163.38 4194.02 4224.64 4256.10 4288.46 4318.04 4349.30 4380.57 4413.23 4443.85 -175.88 -185.08 -194.16 -203.55 -212.91 -221.88 -231.26 -239.07 -247.36 -255.49 -262.99 -270.43 -277.90 -283.95 -289.48 -293.90 -297.10 -299.12 -299.86 -298.73 -295.67 -291.99 -287.95 -283.38 -278.16 -273.50 -269.15 -264.56 -258.07 -250.52 3645.23 3674.73 3704.89 3734.00 3763.84 3793.36 3825.33 3853.77 3884.09 3914.67 3943.55 3971.26 4003.53 4034.31 4064.93 4095.39 4125.45 4156.08 4187.57 4217.75 4250.59 4281.01 4311.36 4342.49 4374.43 4403.64 4434.60 4465.53 4497.59 4527.44 3649.47 3679.38 3709.97 3739.55 3769.86 3799.85 3832.31 3861.18 3891.96 3923.00 3952.31 3980.46 4013.17 4044.29 4075.22 4105.92 4136.14 4166.83 4198.29 4228.32 4260.86 4290.96 4320.97 4351.73 4383.27 4412.13 4442.76 4473.36 4504.99 4534.37 92.76 92.88 93.00 93.12 93.24 93.35 93.46 93.55 93.64 93.73 93.82 93.90 93.97 94.03 94.07 94.10 94.12 94.12 94.10 94.05 93.98 93.90 93.82 93.73 93.64 93.55 93.47 93.39 93.28 93.17 DLS (deg/ 100f) 8.85 12.99 5.11 5.38 8.32 1.47 7.11 10.69 4.38 3.43 1.51 4.46 13.98 2.72 7.95 5.00 9.38 5.98 9.52 13.28 8.88 4.49 2.40 3.64 4.96 6.77 11.51 8.56 14.35 6.04 Page 5 of 8 ------ ------ Srvy tool type Tool qual type ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA _-F MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA .~ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA Drilling & Measurements SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 -------- -------- 8865.94 8894.17 8928.77 8958.93 8990.77 9024.30 9053.30 9084.92 9115.93 9147.36 9180.24 9209.39 9240.52 9271.38 9302.11 9333.59 9364.09 9395.28 9426.43 9458.45 9487.62 9518.88 9550.81 9581.27 9612.62 9643.05 9674.18 9704.87 9736.74 9767.63 ------ ------ Incl angle (deg) ------- ------- Azimuth angle (deg) ------ ------- ------ ------- 88.31 88.28 88.45 88.31 89.82 89.86 88.14 87.63 87.59 88.69 88.52 88.93 89.17 89.48 89.41 89.38 89.10 89.17 89.10 89.89 90.51 90.75 90.37 90.61 90.03 90.30 89.99 89.51 88.42 88.55 74.26 72.18 69.54 68.15 66.80 64.09 61.29 59.07 60.73 59.98 60.88 65.54 66.16 67.59 66.78 65.26 65.41 65.37 65.65 65.16 64.04 63.90 63.22 63.04 62.88 62.52 61.46 60.26 60.76 62.41 ------ ------ Course length (ft) 13-Jan-2003 04:34:03 -------- -------- ---------------- -------- -------- ---------------- TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) --------------- --------------- Total displ (ft) At Azim (deg) ------ -------- -------- ---------------- --------------- ------ -------- -------- ---------------- --------------- 29.75 28.23 34.60 30.16 31.84 33.53 29.00 31.62 31.01 31.43 32.88 29.15 31.13 30.86 30.73 31.48 30.50 31.19 31.15 32.02 29.17 31.26 31.93 30.46 31.35 30.43 31.13 30.69 31.87 30 89 6811.62 6812.46 6813.45 6814.30 6814.82 6814.92 6815.42 6816.59 6817.88 6818.90 6819.70 6820.35 6820.87 6821.23 6821.53 6821.86 6822.27 6822.74 6823.21 6823.49 6823.39 6823.04 6822.73 6822.47 6822.30 6822.21 6822.13 6822.26 6822.84 6823.66 4473.38 4501.29 4535.25 4564.64 4595.50 4627.69 4655.10 4684.49 4713.26 4742.52 4773.15 4800.78 4830.72 4860.55 4890.30 4920.60 4949.86 4979.80 5009.71 5040.44 5068.32 5098.09 5128.43 5157.31 5187.00 5215.77 5245.07 5273.75 5303.46 5332.46 -242.70 -234.55 -223.21 -212.33 -200.14 -186.20 -172.90 -157.19 -141.65 -126.11 -109.89 -96.76 -84.03 -71.91 -59.99 -47.20 -34.47 -21.49 -8.58 4.75 17.26 30.98 45.20 58.96 73.21 87.17 101.79 116.73 132.42 147.11 4556.14 4583.15 4615.82 4643.94 4673.34 4703.84 4729.60 4757.01 4783.81 4811.12 4839.70 4865.71 4894.11 4922.49 4950.81 4979.57 5007.29 5035.64 5063.99 5093.10 5119.45 5147.54 5176.13 5203.30 5231.22 5258.26 5285.74 5312.55 5340.28 5367.44 4562.59 4589.15 4621.21 4648.79 4677.62 4707.52 4732.76 4759.61 4785.91 4812.77 4840.95 4866.67 4894.83 4923.02 4951.18 4979.80 5007.41 5035.69 5063.99 5093.10 5119.48 5147.63 5176.32 5203.63 5231.73 5258.98 5286.72 5313.83 5341.92 5369.46 93.05 92.93 92.77 92.62 92.45 92.27 92.09 91.89 91.70 91.50 91.30 91.14 90.98 90.84 90.69 90.54 90.39 90.24 90.10 89.95 89.81 89.66 89.50 89.35 89.20 89.05 88.90 88.74 88.58 88.43 DLS (deg/ 100f) ----- 4.32 7.37 7.64 4.63 6.36 8.08 11.33 7.20 5.35 4.24 2.78 16.04 2.14 4.74 2.65 4.83 1.04 0.26 0.93 2.90 4.39 0.89 2.44 0.98 1.92 1.48 3.55 4.21 3.76 5.36 Page 6 of 8 ------ ----- ------ Srvy tool type Tool qual type ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ~ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA Drilling & Measurements SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 151 152 153 154 155 156 157 158 159 160 161 162 163 164 165 166 167 168 169 170 171 172 173 174 175 176 177 178 179 180 -------- -------- 9798.26 9829.94 9860.50 9891.14 9922.79 9953.69 9984.58 10016.26 10047.72 10078.75 10110.17 10142.12 10172.98 10203.03 10234.75 10264.08 10296.30 10327.90 10358.62 10390.66 10422.00 10453.14 10483.17 10511.34 10546.64 10576.58 10607.72 10638.95 10669.19 10700.16 ------ ------ Incl angle (deg) ------ ------ 87.80 88.72 89.96 90.65 88.48 87.01 86.18 85.91 86.25 86.60 88.45 91.19 90.78 91.26 90.44 89.96 90.40 90.27 89.58 89.62 90.37 90.06 90.47 89.14 88.79 88.66 89.65 90.78 89.55 91.02 ------- ------- Azimuth angle (deg) ------- ------- 64.04 65.07 68.27 67.73 68.57 67.25 65.10 63.26 61.06 58.77 59.17 60.17 62.03 64.05 64.14 61.99 58.90 58.89 57.95 57.08 56.93 56.02 57.70 55.44 53.43 54.04 54.90 55.13 55.45 56.41 ------ ------ Course length (ft) ------ ------ 30.63 31.68 30.56 30.64 31.65 30.90 30.89 31.68 31.46 31.03 31.42 31.95 30.86 30.05 31.72 29.33 32.22 31.60 30.72 32.04 31.34 31.14 30.03 28.17 35.30 29.94 31.14 31.23 30.24 30.97 13-Jan-2003 04~34~03 -------- -------- ---------------- --------------- -------- -------- ---------------- --------------- TVD depth (ft) -------- -------- 6824.63 6825.59 6825.95 6825.78 6826.02 6827.24 6829.07 6831.26 6833.41 6835.35 6836.70 6836.80 6836.27 6835.74 6835.27 6835.16 6835.06 6834.88 6834.92 6835.14 6835.14 6835.03 6834.89 6834.98 6835.62 6836.29 6836.75 6836.63 6836.54 6836.39 Vertical section (ft) -------- -------- 5361.49 5391.75 5421.26 5451.03 5481.79 5511.78 5541.49 5571.62 5601.20 5629.96 5658.91 5688.52 5717.40 5745.87 5776.10 5803.89 5833.91 5863.04 5891.26 5920.49 5948.96 5977.13 6004.38 6029.88 6061.25 6087.69 6115.38 6143.28 6170.36 6198.25 Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) ---------------- --------------- ---------------- --------------- 160.90 174.51 186.61 198.09 209.86 221.48 233.93 247.69 262.35 277.88 294.06 310.19 325.10 338.72 352.58 365.86 381.75 398.08 414.16 431.37 448.44 465.64 482.05 497.57 518.10 535.80 553.90 571.80 589.02 606.37 5394.77 5423.37 5451.42 5479.83 5509.20 5537.81 5566.02 5594.46 5622.22 5649.01 5675.91 5703.48 5730.50 5757.27 5785.80 5811.95 5839.97 5867.03 5893.20 5920.23 5946.51 5972.47 5997.61 6021.12 6049.83 6073.96 6099.30 6124.89 6149.75 6175.40 5397.17 5426.17 5454.61 5483.41 5513.20 5542.24 5570.93 5599.94 5628.33 5655.84 5683.52 5711.91 5739.71 5767.23 5796.54 5823.45 5852.44 5880.52 5907.74 5935.92 5963.40 5990.59 6016.96 6041.65 6071.97 6097.55 6124.40 6151.52 6177.89 6205.10 88.29 88.16 88.04 87.93 87.82 87.71 87.59 87.46 87.33 87.18 87.03 86.89 86.75 86.63 86.51 86.40 86.26 86.12 85.98 85.83 85.69 85.54 85.40 85.28 85.11 84.96 84.81 84.67 84.53 84.39 ----- DLS (deg/ 100f) 5.86 4.36 11.23 2.86 7.35 6.39 7.45 5.86 7.06 7.45 6.02 9.13 6.17 6.91 2.60 7.51 9.69 0.41 3.80 2.72 2.44 3.09 5.76 9.31 5.78 2.08 4.21 3.69 4.20 5.67 Page 7 of 8 ------ ------ Srvy tool type Tool qual type ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ~ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ~- MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA Drilling & Measurements SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 181 182 183 184 185 186 187 188 189 190 191 192 193 194 195 196 197 198 199 200 201 202 203 204 205 206 207 208 -------- -------- 10730.79 10762.42 10792.16 10825.01 10855.57 10886.86 10919.67 10949.61 10981.65 11013.73 11044.12 11075.17 11107.11 11138.57 11169.56 11199.34 11230.39 11262.13 11293.68 11325.73 11356.67 11387.30 11418.86 11449.83 11479.92 11512.58 11546.74 11600.00 ------ ------ Incl angle (deg) ------ ------ 91.33 90.75 90.34 91.23 91.98 93.15 93.32 91.61 90.13 90.13 89.92 89.79 89.55 89.72 90.17 90.16 90.13 90.23 89.96 89.75 90.85 93.22 95.66 97.70 99.96 100.90 101.49 101.49 ------- ------- Azimuth angle (deg) ------ -------- -------- ------ -------- -------- Course length (ft) TVD depth (ft) Vertical section (ft) 13-Jan-2003 04:34:03 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) --------------- --------------- Total displ (ft) At Azim (deg) ------- ------ -------- -------- ---------------- --------------- ------- ------ -------- -------- ---------------- --------------- 54.74 54.96 54.33 54.57 59.04 60.76 60.86 61.22 61.63 61.41 62.42 62.02 62.07 60.76 57.56 56.33 56.29 56.63 56.92 56.65 57.23 55.44 55.32 54.31 52.97 53.44 53.12 53.12 30.63 31.63 29.74 32.85 30.56 31.29 32.81 29.94 32.04 32.08 30.39 31.05 31.94 31.46 30.99 29.78 31.05 31.74 31.55 32.05 30.94 30.63 31.56 30.97 30.09 32.66 34.16 53.26 6835.76 6835.19 6834.91 6834.46 6833.60 6832.20 6830.35 6829.06 6828.57 6828.50 6828.49 6828.57 6828.75 6828.95 6828.98 6828.89 6828.81 6828.72 6828.66 6828.74 6828.58 6827.49 6825.05 6821.45 6816.83 6810.92 6804.29 6793.68 6225.74 6253.96 6280.44 6309.65 6337.35 6366.37 6396.97 6424.96 6455.01 6485.12 6513.72 6542.99 6573.07 6602.58 6631.20 6658.24 6686.29 6715.00 6743.61 6772.68 6800.77 6828.43 6856.63 6884.06 6910.30 6938.53 6968.00 7013.83 623.68 641.89 659.10 678.19 694.91 710.59 726.57 741.05 756.37 771.67 785.98 800.45 815.42 830.47 846.36 862.60 879.82 897.36 914.65 932.20 949.08 966.05 983.92 1001.65 1019.27 1038.51 1058.55 1089.87 6200.66 6226.52 6250.77 6277.50 6303.05 6330.09 6358.69 6384.86 6413.00 6441.19 6468.00 6495.48 6523.69 6551.31 6577.92 6602.88 6628.71 6655.17 6681.56 6708.37 6734.30 6759.78 6785.67 6810.81 6834.75 6860.47 6887.33 6929.08 6231.95 6259.52 6285.42 6314.02 6341.24 6369.85 6400.07 6427.72 6457.45 6487.25 6515.58 6544.61 6574.45 6603.74 6632.14 6658.98 6686.85 6715.39 6743.87 6772.83 6800.85 6828.46 6856.63 6884.07 6910.33 6938.63 6968.20 7014.27 84.26 84.11 83.98 83.83 83.71 83.60 83.48 83.38 83.27 83.17 83.07 82.97 82.88 82.78 82.67 82.56 82.44 82.32 82.21 82.09 81.98 81.87 81.75 81.63 81.52 81.39 81.26 81.06 DLS (deg/ 100f) 5.54 1.96 2.53 2.81 14.83 6.64 0.60 5.84 4.79 0.69 3.39 1.35 0.77 4.20 10.43 4.13 0.16 1.12 1.26 1.07 4.02 9.69 7.74 7.34 8.70 3.21 1.96 0.00 Page 8 of 8 ----- ------ ------ Srvy tool type Tool qual type ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA .~ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ~ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA Projected to TD b"'n., t" 5-1 09 Survey Report - Geodetic SchlumbopgBr Report Date: 13-Jan-03 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 81.060° Field: Prudhoe Bay Unit· WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: 8-PAD / 8-109 TVD Reference Datum: KB Well: 8-109 TVD Reference Elevation: 64.100 ft relative to M8L Borehole: 8-109 UWUAPI#: 500292313500 Magnetic Declination: +25.830° Survey Name I Date: 8-109 / January 13, 2003 Total Field Strength: 57523.807 nT Tort I AHD I DDlI ERD ratio: 317.773° /7327.03 ft / 6.597 /1.072 Magnetic Dip: 80.820° Grid Coordinate System: NAD27 Alaska 8tate Planes, Zone 4, U8 Feet Declination Date: January 13, 2003 --~ Location LatILong: N 70.35584233, W 149.03414107 Magnetic Declination Model: BGGM 2002 Location Grid NfE VIX: N 5980670.180 ftUS, E 618929.810 ftUS North Reference: True North Grid Convergence Angle: +0.90965438° Total Corr Mag North -> True North: +25.830° Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec Nf-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) C/100ft) (ftUS) (ftUS) 8244.48 89.89 104.74 6804.96 3854.78 -262.98 3943.56 5980469.85 622876.70 N 70.35512105 W 149.00212005 8273.17 91.02 105.34 6804.74 3880.99 -270.43 3971.26 4.46 5980462.85 622904.52 N 70.35510067 W 149.00189512 8306.31 90.54 100.73 6804.28 3911.71 -277.90 4003.53 13.98 5980455.89 622936.91 N 70.35508021 W 149.00163310 8337.68 90.13 101.48 6804.10 3941. 18 -283.94 4034.32 2.72 5980450.34 622967.78 N 70.35506366 W 149.00138318 8368.79 90.23 99.01 6804.00 3970.56 -289.48 4064.93 7.95 5980445.29 622998.47 N 70.35504850 W 149.00113464 8399.57 89.99 97.49 6803.94 3999.97 -293.89 4095.39 5.00 5980441.36 623029.00 N 70.35503639 W 149.00088733 8429.81 90.37 94.68 6803.85 4029.17 -297.10 4125.45 9.38 5980438.63 623059.11 N 70.35502759 W 149.00064321 8460.50 90.23 92.85 6803.69 4059.11 -299.11 4156.08 5.98 5980437.11 623089.75 N 70.35502203 W 149.0003945' 8492.01 90.16 89.85 6803.58 4090.10 -299.85 4187.57 9.52 5980436.86 623121.26 N 70.35501996 W 149.0001386 8522.22 90.58 85.86 6803.39 4120.10 -298.72 4217.76 13.28 5980438.47 623151.41 N 70.35502300 W 148.9998937S-- 8555.20 88.83 83.51 6803.56 4153.01 -295.67 4250.59 8.88 5980442.05 623184.19 N 70.35503129 W 148.99962713 8585.86 87.73 82.68 6804.48 4183.63 -291.99 4281.01 4.49 5980446.22 623214.55 N 70.35504131 W 148.99938008 8616.51 87.21 82.16 6805.83 4214.24 -287.95 4311.37 2.40 5980450.74 623244.83 N 70.35505230 W 148.99913361 8648.02 86.70 81.13 6807.50 4245.71 -283.37 4342.50 3.64 5980455.80 623275.89 N 70.35506474 W 148.99888081 8680.46 85.32 80.30 6809.76 4278.07 -278.15 4374.43 4.96 5980461.53 623307.73 N 70.35507895 W 148.99862147 8710.11 86.87 81.58 6811.78 4307.65 -273.50 4403.64 6.77 5980466.65 623336.86 N 70.35509163 W 148.99838425 8741.39 90.37 82.42 6812.53 4338.91 -269.14 4434.61 11.51 5980471.49 623367.75 N 70.35510347 W 148.99813284 8772.67 92.43 80.71 6811.77 4370.17 -264.56 4465.54 8.56 5980476.57 623398.60 N 70.35511595 W 148.99788167 S-109 ASP Final Surveys.xls Page 1 of 4 1/29/2003-5:24 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NJ-S EJ-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°/1 o Oft) (ftUS) (ftUS) 8805.40 90.61 76.38 6810.90 4402.85 -258.06 4497.59 14.35 5980483.57 623430.55 N 70.35513364 W 148.99762133 8836.19 89.14 75.24 6810.97 4433.51 -250.51 4527.44 6.04 5980491.59 623460.27 N 70.35515421 W 148.99737892 8865.94 88.31 74.26 6811.63 4463.07 -242.69 4556.14 4.32 5980499.87 623488.83 N 70.35517554 W 148.99714589 8894.17 88.28 72.18 6812.47 4491.03 -234.55 4583.15 7.37 5980508.44 623515.71 N 70.35519774 W 148.99692650 8928.77 88.45 69.54 6813.46 4525.06 -223.21 4615.82 7.64 5980520.29 623548.20 N 70.35522867 W 148.99666116 8958.93 88.31 68.15 6814.31 4554.53 -212.33 4643.94 4.63 5980531.62 623576.13 N 70.35525834 W 148.99643281 8990.77 89.82 66.80 6814.83 4585.47 -200.13 4673.34 6.36 5980544.28 623605.34 N 70.35529161 W 148.99619398 9024.30 89.86 64.09 6814.92 4617.76 -186.20 4703.84 8.08 5980558.69 623635.61 N 70.35532962 W 148.99594629 9053.30 88.14 61.29 6815.43 4645.27 -172.90 4729.60 11.33 5980572.40 623661.15 N 70.35536591 W 148.99573706 9084.92 87.63 59.07 6816.60 4674.79 -157.19 4757.01 7.20 5980588.54 623688.31 N 70.35540879 W 148.9955143 9115.93 87.59 60.73 6817.89 4703.69 -141.65 4783.82 5.35 5980604.50 623714.86 N 70.35545119 W 148.99529666~ 9147.36 88.69 59.98 6818.91 4733.07 -126.11 4811.12 4.24 5980620.47 623741.91 N 70.35549359 W 148.99507489 9180.24 88.52 60.88 6819.71 4763.83 -109.89 4839.71 2.78 5980637.14 623770.23 N 70.35553785 W 148.99484266 9209.39 88.93 65.54 6820.36 4791.57 -96.76 4865.71 16.04 5980650.68 623796.03 N 70.35557368 W 148.99463142 9240.52 89.17 66.16 6820.87 4821.60 -84.02 4894.11 2.14 5980663.87 623824.22 N 70.35560842 W 148.99440073 9271.38 89.48 67.59 6821.24 4851.52 -71.90 4922.49 4.74 5980676.43 623852.40 N 70.35564148 W 148.99417024 9302.11 89.41 66.78 6821.54 4881.35 -59.99 4950.82 2.65 5980688.79 623880.53 N 70.35567398 W 148.99394018 9333.59 89.38 65.26 6821.87 4911.75 -47.20 4979.58 4.83 5980702.04 623909.08 N 70.35570887 W 148.99370658 9364.09 89.10 65.41 6822.27 4941.10 -34.47 5007.29 1.04 5980715.21 623936.59 N 70.35574359 W 148.99348146 9395.28 89.17 65.37 6822.74 4971.13 -21.48 5035.65 0.26 5980728.64 623964.73 N 70.35577902 W 148.99325115 9426.43 89.10 65.65 6823.21 5001.14 -8.57 5063.99 0.93 5980742.00 623992.86 N 70.35581424 W 148.99302093 9458.45 89.89 65.16 6823.50 5031.97 4.76 5093.10 2.90 5980755.78 624021.76 N 70.35585059 W 148.99278445 9487.62 90.51 64.04 6823.39 5059.94 17.27 5119.45 4.39 5980768.71 624047.90 N 70.35588472 W 148.99257042 9518.88 90.75 63.90 6823.05 5089.82 30.98 5147.54 0.89 5980782.87 624075.77 N 70.35592214 W 148.99234227 9550.81 90.37 63.22 6822.74 5120.27 45.20 5176.13 2.44 5980797.54 624104.12 N 70.35596093 W 148.9921100r 9581.27 90.61 63.04 6822.48 5149.25 58.97 5203.30 0.98 5980811.73 624131.07 N 70.35599848 W 148.991889J, --' 9612.62 90.03 62.88 6822.30 5179.05 73.22 5231 .22 1.92 5980826.43 624158.76 N 70.35603737 W 148.99166252 9643.05 90.30 62.52 6822.21 5207.93 87.18 5258.26 1.48 5980840.81 624185.57 N 70.35607544 W 148.99144287 9674.18 89.99 61 .46 6822.14 5237.35 101.79 5285.74 3.55 5980855.86 624212.82 N 70.35611533 W 148.99121962 9704.87 89.51 60.26 6822.27 5266.15 116.74 5312.55 4.21 5980871.23 624239.38 N 70.35615610 W 148.99100187 9736.74 88.42 60.76 6822.85 5295.99 132.42 5340.29 3.76 5980887.35 624266.86 N 70.35619890 W 148.99077656 9767.63 88.55 62.41 6823.66 5325.10 147.12 5367.44 5.36 5980902.47 624293.78 N 70.35623899 W 148.99055594 9798.26 87.80 64.04 6824.64 5354.24 160.91 5394.77 5.86 5980916.69 624320.89 N 70.35627661 W 148.99033393 9829.94 88. 72 65.07 6825.60 5384.60 174.51 5423.37 4.36 5980930.75 624349.26 N 70.35631372 W 148.99010166 9860.50 89.96 68.27 6825.95 5414.20 186.61 5451 .42 11.23 5980943.29 624377.11 N 70.35634672 W 148.98987377 S-109 ASP Final Surveys.xls Page 2 of 4 1/29/2003-5:24 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI·W DLS Northing Easting Latitude Longitude (11) (0) (0) (ft) (ft) (11) (ft) (0/100ft) (ftUS) (ftUS) 9891.14 90.65 67.73 6825.79 5444.04 198.09 5479.83 2.86 5980955.22 624405.33 N 70.35637802 W 148.98964302 9922.79 88.48 68.57 6826.03 5474.89 209.87 5509.20 7.35 5980967.46 624434.52 N 70.35641014 W 148.98940443 9953.69 87.01 67.25 6827.24 5504.96 221.48 5537.81 6.39 5980979.52 624462.93 N 70.35644180 W 148.98917205 9984.58 86.18 65.10 6829.08 5534.75 233.93 5566.02 7.45 5980992.42 624490.94 N 70.35647577 W 148.98894293 10016.26 85.91 63.26 6831.27 5565.00 247.70 5594.47 5.86 5981006.64 624519.16 N 70.35651331 W 148.98871184 10047.72 86.25 61.06 6833.42 5594.69 262.36 5622.22 7.06 5981021.73 624546.67 N 70.35655330 W 148.98848640 10078.75 86.60 58.77 6835.35 5623.57 277.88 5649.01 7.45 5981037.68 624573.22 N 70.35659565 W 148.98826871 10110.17 88.45 59.17 6836.71 5652.66 294.06 5675.91 6.02 5981054.28 624599.85 N 70.35663980 W 148.98805019 10142.12 91.19 60.17 6836.81 5682.40 310.19 5703.49 9.13 5981070.85 624627.16 N 70.35668381 W 148.98782618 10172.98 90.78 62.03 6836.28 5711.40 325.10 5730.50 6.17 5981086.18 624653.93 N 70.35672449 W 148.9876067 10203.03 91.26 64.05 6835.74 5739.97 338.72 5757.28 6.91 5981100.23 624680.49 N 70.35676165 W 148.9873892~ 10234.75 90.44 64.14 6835.27 5770.31 352.58 5785.81 2.60 5981114.53 624708.79 N 70.35679944 W 148.98715745 10264.08 89.96 61.99 6835.17 5798.20 365.87 5811.95 7.51 5981128.23 624734.72 N 70.35683568 W 148.98694504 10296.30 90.40 58.90 6835.07 5828.35 381.76 5839.98 9.69 5981144.56 624762.49 N 70.35687903 W 148.98671737 10327.90 90.27 58.89 6834.88 5857.62 398.08 5867.03 0.41 5981161.31 624789.28 N 70.35692357 W 148.98649755 10358.62 89.58 57.95 6834.92 5885.97 414.17 5893.20 3.80 5981177.81 624815.19 N 70.35696746 W 148.98628494 10390.66 89.62 57.08 6835.15 5915.34 431.38 5920.23 2.72 5981195.44 624841.94 N 70.35701441 W 148.98606536 10422.00 90.37 56.93 6835.15 5943.96 448.44 5946.51 2.44 5981212.92 624867.94 N 70.35706098 W 148.98585180 10453.14 90.06 56.02 6835.03 5972.28 465.64 5972.47 3.09 5981230.53 624893.62 N 70.35710791 W 148.98564089 10483.17 90.47 57.70 6834.89 5999.67 482.06 5997.62 5.76 5981247.34 624918.50 N 70.35715270 W 148.98543659 10511.34 89.14 55.44 6834.99 6025.30 497.57 6021.12 9.31 5981263.23 624941.76 N 70.35719504 W 148.98524560 10546.64 88.79 53.43 6835.63 6056.85 518.10 6049.83 5.78 5981284.21 624970.14 N 70.35725106 W 148.98501233 10576.58 88.66 54.04 6836.29 6083.44 535.81 6073.97 2.08 5981302.29 624993.98 N 70.35729937 W 148.98481622 10607.72 89.65 54.90 6836.75 6111.28 553.90 6099.31 4.21 5981320.79 625019.03 N 70.35734875 W 148.98461034 10638.95 90.78 55.13 6836.64 6139.34 571.81 6124.89 3.69 5981339.09 625044.33 N 70.35739761 W 148.984402A . 1 0669.19 89.55 55.45 6836.55 6166.58 589.03 6149.75 4.20 5981356.70 625068.91 N 70.35744459 W 148.9842004, 10700.16 91.02 56.41 6836.40 6194.61 606.37 6175.40 5.67 5981374.46 625094.28 N 70.35749193 W 148.98399202' 10730.79 91.33 54.74 6835.77 6222.25 623.69 6200.66 5.54 5981392.17 625119.26 N 70.35753917 W 148.98378678 10762.42 90.75 54.96 6835.19 6250.63 641.89 6226.52 1.96 5981410.78 625144.82 N 70.35758885 W 148.98357667 10792.16 90.34 54.33 6834.91 6277.26 659.10 6250.77 2.53 5981428.37 625168.80 N 70.35763580 W 148.98337959 10825.01 91.23 54.57 6834.46 6306.63 678.20 6277.50 2.81 5981447.89 625195.21 N 70.35768791 W 148.98316244 10855.57 91.98 59.04 6833.60 6334.47 694.92 6303.05 14.83 5981465.01 625220.50 N 70.35773354 W 148.98295479 10886.86 93.15 60.76 6832.20 6363.62 710.59 6330.10 6.64 5981481.11 625247.28 N 70.35777630 W 148.98273508 10919.67 93.32 60.86 6830.35 6394.36 726.57 6358.69 0.60 5981497.54 625275.62 N 70.35781988 W 148.98250273 10949.61 91.61 61.22 6829.06 6422.46 741.05 6384.87 5.84 5981512.43 625301.56 N 70.35785938 W 148.98229010 S-109 ASP Final Surveys.xls Page 3 of 4 1/29/2003-5:24 PM Grid Coordinates Geographic Coordinates Station ID MD Inct Azim TVD VSec NI-S EJ-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 10981.65 90.13 61.63 6828.58 6452.63 756.38 6413.00 4.79 5981528.20 625329.44 N 70.35790118 W 148.98206152 11013.73 90.13 61.41 6828.50 6482.86 771.67 6441.20 0.69 5981543.94 625357.39 N 70.35794290 W 148.98183242 11044.12 89.92 62.42 6828.49 6511.57 785.98 6468.01 3.39 5981558.67 625383.97 N 70.35798192 W 148.98161459 11075.17 89.79 62.02 6828.57 6540.96 800.45 6495.48 1.35 5981573.57 625411.20 N 70.35802139 W 148.98139140 11107.11 89.55 62.07 6828.75 6571 .16 815.43 6523,69 0.77 5981588.99 625439.17 N 70.35806223 W 148.98116218 11138.57 89.72 60.76 6828.95 6600.78 830.48 6551.32 4.20 5981604.48 625466.55 N 70.35810328 W 148.98093773 11169.56 90.17 57.56 6828.98 6629.53 846.36 6577.92 10.43 5981620.78 625492.90 N 70.35814661 W 148.98072157 11199.34 90.16 56.33 6828.90 6656.71 862.60 6602.88 4.13 5981637.42 625517.60 N 70.35819093 W 148.98051876 11230.39 90.13 56.29 6828.82 6684.91 879.83 6628.71 0.16 5981655.05 625543.15 N 70.35823792 W 148.98030883 11262.13 90.23 56.63 6828.72 6713.77 897.36 6655.17 1.12 5981673.00 625569.32 N 70.35828576 W 148.9800938 11293.68 89.96 56.92 6828.67 6742.53 914.65 6681.56 1.26 5981690.70 625595.44 N 70.35833293 W 148.9798794~ 11325.73 89.75 56.65 6828.75 6771.74 932.21 6708.38 1.07 5981708.68 625621.97 N 70.35838082 W 148.97966151 11356.67 90.85 57.23 6828.59 6799.98 949.09 6734.30 4.02 5981725.97 625647.62 N 70.35842687 W 148.97945081 11387.30 93.22 55.44 6827.50 6827.78 966.05 6759.78 9.69 5981743.33 625672.82 N 70.35847315 W 148.97924380 11418.86 95.66 55.32 6825.06 6856.14 983.93 6785.67 7.74 5981761.62 625698.42 N 70.35852192 W 148.97903340 11449.83 97.70 54.31 6821 .45 6883.73 1001.65 6810.81 7.34 5981779.74 625723.28 N 70.35857028 W 148.97882911 11479.92 99.96 52.97 6816.84 6910.12 1019.27 6834.75 8.70 5981797.74 625746.93 N 70.35861837 W 148.97863454 11512.58 100.90 53.44 6810.92 6938.52 1038.51 6860.47 3.21 5981817.38 625772.34 N 70.35867086 W 148.97842551 11546.74 101.49 53.12 6804.29 6968.16 1058.55 6887.33 1.96 5981837.84 625798.88 N 70,35872553 W 148.97820722 11600.00 101.49 53.12 6793.68 7014.27 1089.87 6929.08 0.00 5981869.82 625840.12 N 70.35881100 W 148.97786793 -' S-109 ASP Final Surveys,xls Page 4 of 4 1/29/2003-5:24 PM DRILLING & MEASUREMENTS SCHLUMBERGER Survey report 16-Jan-2003 10:56:54 Page Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Aurora Well. . . . . . . . . . . . . . . . . . . . .: S-109 PB1 API number...............: 50-029-23135-70 Engineer. . . . . . . . . . . . . . . . .: E. Roux Spud date..... ...........: Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: COUNTY: . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE:.....:.............: Alaska 31-Dec-02 09-Jan-03 107 0.00 ft 8446.50 ft ----- Geomagnetic data ---------------------- Magnetic model...... .....: BGGM version 2000 Magnetic date............: 31-Dec-2002 Magnetic field strength..: 1150.02 RCNT Magnetic dec (+E/W-).....: 25.97 degrees Magnetic dip.............: 80.81 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.84 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.84 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum.... . . . . . .: MEAN SEA LEVEL Depth reference..........: Driller1s Pipe Tally GL above permanent.......: 35.49 ft KB above permanent. ...... : N/A - Top Drive DF above permanent.......: 64.10 ft ----- MWD survey Reference Reference G........... ...: Reference R......... . . . . . : Reference Dip............: Tolerance of G...........: Tolerance of R...........: Tolerance of Dip.... .....: ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: N 70.355842330 Departure (+E/W-)........: W 149.03414107 Azimuth from rotary table to target: 81.70 degrees [(c)2003 Drilling & Measurements IDEAL ID6_1C_10J Criteria --------- 1002.68 mGal 1150.02 RCNT 80.82 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees 1 of 5 £ -~ -~' DRILLING & MEASUREMENTS SCHLUMBERGER Survey Report 16-Jan-2003 10:56:54 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 1 2 3 4 5 0.00 77.00 170.00 265.00 350.00 449.00 550.00 650.00 726.00 825.00 925.00 1025.00 1125.00 1195.00 1315.75 1408.67 1498.59 1592.39 1685.62 1778.58 1871.86 1964.47 2058.45 2153.60 2245.19 2339.43 2432.84 2524.85 2618.26 2712.50 0.00 0.37 0.18 1.95 3.87 5.57 5.61 6.45 7.71 9.59 11.35 12.97 15.59 17.17 19.19 18.78 18.50 17.74 18.89 19.66 20.37 19.88 21.76 23.24 25.16 27.30 29.66 29.83 30.87 30.79 0.00 315.63 65.86 103.28 102.62 101.19 101.50 97.94 98.46 98.70 90.93 94.90 90.42 91.10 91.58 91.28 91.03 90.62 91.12 88.85 88.94 88.88 88.38 90.14 90.65 89.17 87.41 87.15 87.71 87.48 0.00 77.00 93.00 95.00 85.00 99.00 101.00 100.00 76.00 99.00 100.00 100.00 100.00 70.00 120.75 92.92 89.92 93.80 93.23 92.96 93.28 92.61 93.98 95.15 91.59 94.24 93.41 92.01 93.41 94.24 0.00 77.00 170.00 264.98 349.87 448.53 549.05 648.49 723.91 821.78 920.12 1017.87 1114.78 1181.93 1296.65 1384.51 1469.72 1558.87 1647.37 1735.12 1822.77 1909.72 1997.56 2085.47 2169.00 2253.54 2335.64 2415.52 2496.13 2577.06 0.00 -0.15 -0.18 1.46 5.49 13.14 22.40 32.40 41.38 55.62 73.30 93.94 118.16 137.65 174.79 204.58 232.93 261.73 290.65 321.02 352.69 384.30 417.46 453.55 490.66 531.88 576.13 621.56 668.52 716.56 0.00 0.18 0.45 0.14 -0.82 -2.48 -4.42 -6.17 -7.51 -9.73 -11.15 -12.27 -13.33 -13.59 -14.48 -15.24 -15.82 -16.24 -16.69 -16.67 -16.05 -15.45 -14.64 -14.19 -14.45 -14.37 -13.01 -10.85 -8.73 -6.71 0.00 -0.17 -0.25 1.46 5.67 13.64 23.29 33.64 42.91 57.63 75.71 96.73 121.35 141.09 178.75 208.97 237.70 266.87 296.17 326.85 358.77 390.63 424.02 460.42 497.96 539.61 584.12 629.72 676.87 725.13 0.00 0.25 0.52 1.47 5.72 13.86 23.70 34.20 43.56 58.45 76.52 97.50 122.08 141.74 179.34 209.52 238.23 267.37 296.64 327.27 359.13 390.93 424.27 460.64 498.17 539.80 584.27 629.82 676.93 725.16 0.00 315.63 331.01 84.45 98.21 100.30 100.74 100.39 99.92 99.58 98.38 97.23 96.27 95.50 94.63 94.17 93.81 93.48 93.23 92.92 92.56 92.26 91.98 91.77 91.66 91.53 91.28 90.99 90.74 90.53 DLS (deg/ 100f) 0.00 0.48 0.50 1.91 2.26 1.72 0.05 0.92 1.66 1.90 2.25 1.82 2.84 2.27 1.68 0.45 0.32 0.82 1.24 1.16 0.76 0.53 2.01 1.71 2.11 2.37 2.68 0.23 1.15 0.15 Page 2 of 5 ------ ------ Srvy tool type Tool qual type ------ ------ TIP GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO -" GYRO GYRO GYRO GYRO MWD_IFR_MSA Ml"tJD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ,~' MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA DRILLING & MEASUREMENTS SCHLUMBERGER Survey Report -------- ------ -------- ------ Seq Measured # depth (ft) Incl angle (deg) ------- ------ -------- -------- ------- ------ -------- -------- Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) 16-Jan-2003 10:56:54 ---------------- --------------- ---------------- --------------- Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 2805.35 2898.76 2984.54 3030.96 3125.55 3218.25 3310.73 3404.25 3497.73 3590.53 3683.68 3776.79 3870.20 3963.46 4056.89 4149.50 4242.84 4335.30 4427.93 4520.75 4614.52 4708.76 4802.23 4894.58 4987.70 5079.93 5173.57 5267.45 5360.61 5452.16 31.77 31.40 31.14 30.52 30.48 30.66 30.77 30.67 30.26 30.31 30.27 29.47 28.88 28.85 28.22 28.39 28.06 28.00 27.85 29.62 30.09 29.40 29.16 30.47 32.04 32.23 32.51 32.68 33.06 31.36 86.60 86.70 86.57 86.27 86.38 86.16 85.93 88.38 88.50 87.54 87.05 89.82 89.14 88.86 90.92 90.50 89.66 89.08 92.74 93.47 93.59 93.48 92.98 92.35 92.91 92.32 91.67 91.00 91.10 90.80 92.85 93.41 85.78 46.42 94.59 92.70 92.48 93.52 93.48 92.80 93.15 93.11 93.41 93.26 93.43 92.61 93.34 92.46 92.63 92.82 93.77 94.24 93.47 92.35 93.12 92.23 93.64 93.88 93.16 91.55 2656.41 2735.98 2809.30 2849.16 2930.66 3010.48 3089.98 3170.38 3250.96 3331.09 3411.53 3492.27 3573.83 3655.50 3737.59 3819.12 3901.37 3982.98 4064.83 4146.22 4227.54 4309.36 4390.89 4471.02 4550.62 4628.72 4707.81 4786.90 4865.15 4942.61 764.56 813.31 857.67 881.37 929.23 976.22 1023.32 1070.87 1117.94 1164.45 1211.21 1257.25 1302.37 1347.02 1391.20 1434.57 1478.24 1521.30 1564.10 1607.84 1653.53 1699.29 1744.08 1789.16 1836.59 1884.76 1934.09 1983.95 2033.84 2082.00 -4.21 -1.35 1.26 2.74 5.82 8.89 12.15 14.52 15.81 17.43 19.64 20.92 21.33 22.12 22.21 21.67 21.61 22.08 21.40 18.97 16.10 13.22 10.64 8.51 6.29 4.05 2.31 1.13 0.20 -0.61 773.27 822.11 866.56 890.30 938.21 985.26 1032.38 1080.09 1127.47 1174.24 1221.17 1267.51 1313.04 1358.06 1402.68 1446.59 1490.73 1534.18 1577.53 1622.09 1668.68 1715.35 1760.99 1806.85 1855.12 1904.12 1954.23 2004.78 2055.34 2104.13 773.28 822.11 866.56 890.31 938.23 985.30 1032.45 1080.19 1127.58 1174.37 1221.32 1267.68 1313.22 1358.24 1402.86 1446.75 1490.89 1534.34 1577.68 1622.20 1668.76 1715.40 1761.02 1806.87 1855.13 1904.13 1954.23 2004.78 2055.34 2104.13 90.31 90.09 89.92 89.82 89.64 89.48 89.33 89.23 89.20 89.15 89.08 89.05 89.07 89.07 89.09 89.14 89.17 89.18 89.22 89.33 89.45 89.56 89.65 89.73 89.81 89.88 89.93 89.97 89.99 90.02 DLS (deg/ 100f) 1.16 0.40 0.31 1.38 0.07 0.23 0.17 1.34 0.44 0.52 0.27 1.71 0.72 0.15 1.25 0.28 0.55 0.30 1.86 1.94 0.51 0.73 0.37 1.46 1.71 0.40 0.48 0.42 0.41 1.87 ~ Page 3 of 5 ------ ------ Srvy tool type Tool qual type ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA Interpolated MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA .~ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA -' MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA DRILLING & MEASUREMENTS SCHLUMBERGER Survey Report 16-Jan-2003 10:56:54 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 5544.57 5638.06 5730.76 5824.05 5918.28 6013.07 6106.73 6200.27 6293.77 6386.86 6480.48 6574.24 6667.36 6760.54 6853.79 6947.19 7039.47 7132.00 7224.51 7317.65 7410.67 7504.34 7597.32 7629.92 7660.49 7690.55 7723.59 7760.87 7870.48 7900.45 29.16 29.00 28.94 28.41 29.18 29.28 28.75 29.01 30.05 29.85 29.24 30.56 33.63 36.27 36.28 36.67 38.96 42.03 44.93 51.57 57.19 61.14 63.08 63.66 63.33 63.33 63.83 64.00 71.13 73.97 91.74 92.91 91.55 90.61 92.36 92.69 92.50 94.62 95.18 94.61 94.64 95.02 96.73 96.55 94.28 90.57 89.72 90.96 93.69 97.07 100.13 101.23 101.70 101.54 101.09 101.48 101.34 101.89 108.81 109.00 92.41 93.49 92.70 93.29 94.23 94.79 93.66 93.54 93.50 93.09 93.62 93.76 93.12 93.18 93.25 93.40 92.28 92.53 92.51 93.14 93.02 93.67 92.98 32.60 30.57 30.06 33.04 37.28 109.61 29.97 5022.42 5104.13 5185.23 5267.08 5349.66 5432.38 5514.28 5596.19 5677.54 5758.20 5839.65 5920.93 5999.81 6076.17 6151.35 6226.47 6299.36 6369.72 6436.85 6498.84 6553.01 6601.01 6644.50 6659.11 6672.76 6686.25 6700.95 6717.34 6759.19 6768.18 2127.92 2172.58 2216.72 2260.88 2305.60 2351.06 2395.67 2439.88 2484.75 2529.99 2574.99 2620.50 2668.45 2720.03 2773.62 2828.15 2884.11 2943.50 3006.04 3073.48 3145.76 3221.80 3299.13 3326.53 3352.30 3377.61 3405.46 3436.94 3529.55 3554.98 -1.63 -3.47 -5.22 -6.07 -7.25 -9.29 -11.35 -14.16 -18.10 -22.06 -25.78 -29.72 -34.82 -40.99 -46.19 -48.53 -48.66 -49.04 -51.66 -58.28 -69.65 -84.57 -100.90 -106.77 -112.14 -117.40 -123.25 -129.99 -156.93 -166.19 2150.68 2196.08 2240.94 2285.70 2331.06 2377.31 2422.69 2467.77 2513.69 2559.99 2606.01 2652.58 2701.78 2754.80 2809.71 2865.17 2921.74 2981.82 3045.40 3114.51 3189.22 3268.24 3348.77 3377.32 3404.14 3430.49 3459.49 3492.29 3589.81 3616.85 2150.68 2196.08 2240.95 2285.70 2331.08 2377.32 2422.72 2467.81 2513.75 2560.09 2606.13 2652.74 2702.00 2755.10 2810.09 2865.58 2922.14 2982.22 3045.84 3115.06 3189.98 3269.33 3350.29 3379.01 3405.99 3432.49 3461.69 3494.71 3593.23 3620.67 90.04 90.09 90.13 90.15 90.18 90.22 90.27 90.33 90.41 90.49 90.57 90.64 90.74 90.85 90.94 90.97 90.95 90.94 90.97 91.07 91.25 91.48 91.73 91.81 91.89 91.96 92.04 92.13 92.50 92.63 DLS (deg/ 100f) 2.44 0.63 0.71 0.75 1.21 0.20 0.57 1.13 1.15 0.37 0.65 1.42 3.44 2.84 1.44 2.40 2.54 3.43 3.73 7.62 6.61 4.34 2.13 1.83 1.70 1.16 1.56 1.40 8.73 9.50 Page 4 of 5 ------ ------ Srvy tool type Tool qual type ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA ~' MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA -' MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA DRILLING & MEASUREMENTS SCHLUMBERGER Survey Report 16-Jan-2003 10:56:54 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 7931.45 7963.02 7995.02 8026.01 8057.55 8088.58 8122.03 8151.56 8183.00 8214.64 8244.48 8277.31 8307.69 8339.37 8369.44 8393.81 8446.50 76.70 79.75 80.00 81.56 83.73 83.91 85.77 88.89 90.23 90.13 89.89 90.92 92.29 92.26 90.03 89.72 89.72 108.73 105.93 107.57 108.17 106.68 107.10 105.61 105.12 105.44 104.36 104.74 105.92 106.96 107.40 106.90 106.74 106.74 31.00 31.57 32.00 30.99 31.54 31.03 33.45 29.53 31.44 31.64 29.84 32.83 30.38 31.68 30.07 24.37 52.69 6776.02 6782.47 6788.09 6793.06 6797.10 6800.44 6803.45 6804.82 6805.06 6804.96 6804.96 6804.73 6803.87 6802.62 6802.02 6802.07 6802.33 [(c)2003 Drilling & Measurements IDEAL ID6_1C_10] 3581.66 3609.52 3638.05 3665.51 3693.69 3721.60 3751.88 3778.89 3807.70 3836.78 3864.28 3894.36 3921.94 3950.51 3977.66 3999.72 4047.46 -175.88 -185.08 -194.16 -203.55 -212.91 -221.88 -231.26 -239.07 -247.36 -255.49 -262.99 -271.67 -280.26 -289.61 -298.48 -305.53 -320.70 3645.23 3674.73 3704.89 3734.00 3763.84 3793.36 3825.33 3853.77 3884.09 3914.67 3943.55 3975.21 4004.34 4034.58 4063.31 4086.63 4137.09 3649.47 3679.38 3709.97 3739.55 3769.86 3799.85 3832.31 3861.18 3891.96 3923.00 3952.31 3984.48 4014.13 4044.96 4074.25 4098.04 4149.50 92.76 92.88 93.00 93.12 93.24 93.35 93.46 93.55 93.64 93.73 93.82 93.91 94.00 94.11 94.20 94.28 94.43 DLS (deg/ 100f) 8.85 12.99 5.11 5.38 8.32 1.47 7.11 10.69 4.38 3.43 1.51 4.77 5.66 1.39 7.60 1.43 0.00 Page 5 of 5 ------ ------ Srvy tool type Tool qual type ------ ------ MWD IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA _/ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA Projected to TD ~ i,r-. ~........\ Utj S-109PB1 SChlumbepuer Survey Report - Geodetic Report Date: 16-Jan-03 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 94.430° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: S-PAD / S-109 TVD Reference Datum: KB Well: S-109 TVD Reference Elevation: 64.100 ft relative to MSL Borehole: S-109PB1 UWVAPI#: 500292313570 Magnetic Declination: +25.823° Survey Name / Date: S-1 09PB 1 / January 16, 2003 Total Field Strength: 57524.105 nT Tort I AHD / DDI / ERD ratio: 149.727° /4177.45 ft / 5.890 I 0.614 Magnetic Dip: 80.820° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: January 20, 2003 -" Location LatlLong: N 70.35584233, W 149.034141 Oï Magnetic Declination Model: BGGM 2002 Location Grid NIE Y/X: N 5980670.180 ftUS, E 618929.810 ftUS North Reference: True North Grid Convergence Angle: +0.90965438° Total Corr Mag North -> True North: +25.823° Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S Ef-W DLS Northing Easting Latitude Longitude (ft) n (0) (ft) (ft) (ft) (ft) (°/1 o Oft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5980670.18 618929.81 N 70.35584233 W 149.03414107 77.00 0.37 315.63 77.00 -0.19 0.18 -0.17 0.48 5980670.35 618929.63 N 70.35584281 W 149.03414249 170.00 0.18 65.86 170.00 -0.28 0.45 -0.25 0.50 5980670.63 618929.55 N 70.35584356 W 149.03414311 265.00 1.95 103.28 264.98 1.44 0.14 1.46 1.91 5980670.34 618931.27 N 70.35584272 W 149.03412923 350.00 3.87 102.62 349.87 5.71 -0.82 5.67 2.26 5980669.45 618935.49 N 70.35584010 W 149.03409507 449.00 5.57 101.19 448.53 13.79 -2.48 13.64 1.72 5980667.92 618943.49 N 70.35583556 W 149.03403032 550.00 5.61 101.50 549.05 23.56 -4.42 23.29 0.05 5980666.14 618953.16 N 70.35583027 W 149.03395199 650.00 6.45 97.94 648.49 34.01 -6.17 33.64 0.92 5980664.55 618963.54 N 70.35582549 W 149.03386792 726.00 7.71 98.46 723.91 43.36 -7.51 42.91 1.66 5980663.36 618972.83 N 70.35582183 W 149.03379264 825.00 9.59 98.70 821 .78 58.21 -9.73 57.63 1.90 5980661.37 618987.58 N 70.35581575 W 149.03367310 ~ 925.00 11.35 90.93 920.12 76.34 -11.15 75.71 2.25 5980660.23 619005.68 N 70.35581187 W 149.03352633 1025.00 12.97 94.90 1017.87 97.39 -12.27 96.73 1.82 5980659.45 619026.71 N 70.35580881 W 149.03335563 1125.00 15.59 90.42 1114.78 122.02 -13.33 121.35 2.84 5980658.78 619051.35 N 70.35580592 W 149.03315569 1195.00 17.17 91.10 1181.93 141.72 -13.59 141.09 2.27 5980658.83 619071.08 N 70.35580519 W 149.03299542 1315.75 19.19 91.58 1296.65 179.34 -14.48 178.75 1.68 5980658.54 619108.75 N 70.35580276 W 149.03268960 1408.67 18.78 91.28 1384.51 209.52 -15.24 208.97 0.45 5980658.26 619138.98 N 70.35580069 W 149.03244422 1498.59 18.50 91.03 1469.72 238.22 -15.82 237.70 0.32 5980658.14 619167.71 N 70.35579911 W 149.03221089 1592.39 17.74 90.62 1558.87 267.33 -16.24 266.87 0.82 5980658.18 619196.88 N 70.35579795 W 149.03197403 S-109PB1 ASP Final Surveys.xls Page 1 of 4 1/29/2003-5:24 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD V5ec NI-5 EJ-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°/1 DDft) (ftUS) (ftUS) 1685.62 18.89 91.12 1647.37 296.57 -16.69 296.17 1.24 5980658.20 619226.18 N 70.35579672 W 149.03173618 1778.58 19.66 88.85 1735.12 327.16 -16.67 326.85 1.16 5980658.70 619256.85 N 70.35579677 W 149.03148705 1871.86 20.37 88.94 1822.77 358.93 -16.05 358.77 0.76 5980659.83 619288.76 N 70.35579845 W 149.03122785 1964.47 19.88 88.88 1909.72 390.65 -15.45 390.63 0.53 5980660.94 619320.60 N 70.35580010 W 149.03096916 2058.45 21.76 88.38 1997.56 423.88 -14.64 424.02 2.01 5980662.27 619353.97 N 70.35580230 W 149.03069801 2153.60 23.24 90.14 2085.47 460.14 -14.19 460.42 1.71 5980663.30 619390.36 N 70.35580353 W 149.03040240 2245.19 25.16 90.65 2169.00 497.59 -14.45 497.96 2.11 5980663.63 619427.90 N 70.35580280 W 149.03009755 2339.43 27.30 89.17 2253.54 539.11 -14.37 539.61 2.37 5980664.38 619469.53 N 70.35580302 W 149.02975938 2432.84 29.66 87.41 2335.64 583.38 -13.01 584.12 2.68 5980666.44 619514.02 N 70.35580672 W 149.02939792 2524.85 29.83 87.15 2415.52 628.68 -10.85 629.72 0.23 5980669.33 619559.57 N 70.35581262 W 149.02902765 '~-' 2618.26 30.87 87.71 2496.13 675.53 -8.73 676.87 1.15 5980672.19 619606.68 N 70.35581838 W 149.02864479 2712.50 30.79 87.48 2577.06 723.48 -6.71 725.13 0.15 5980674.98 619654.89 N 70.35582391 W 149.02825295 2805.35 31.77 86.60 2656.41 771.29 -4.21 773.27 1.16 5980678.24 619702.98 N 70.35583071 W 149.02786202 2898.76 31.40 86.70 2735.98 819.76 -1.35 822.11 0.40 5980681.88 619751.77 N 70.35583851 W 149.02746543 2984.54 31.14 86.57 2809.30 863.87 1.26 866.56 0.31 5980685.20 619796.17 N 70.35584563 W 149.02710449 3030.96 30.52 86.27 2849.16 887.43 2.74 890.30 1.38 5980687.06 619819.88 N 70.35584968 W 149.02691169 3125.55 30.48 86.38 2930.66 934.96 5.82 938.21 0.07 5980690.89 619867.73 N 70.35585807 W 149.02652266 3218.25 30.66 86.16 3010.48 981.63 8.89 985.26 0.23 5980694.71 619914.72 N 70.35586644 W 149.02614063 3310.73 30.77 85.93 3089.98 1028.36 12.15 1032.38 0.17 5980698.71 619961.78 N 70.35587532 W 149.02575798 3404.25 30.67 88.38 3170.38 1075.74 14.52 1080.09 1.34 5980701.84 620009.44 N 70.35588178 W 149.02537060 3497.73 30.26 88.50 3250.96 1122.88 15.81 1127.47 0.44 5980703.88 620056.79 N 70.35588529 W 149.02498588 3590.53 30.31 87.54 3331.09 1169.38 17.43 1174.24 0.52 5980706.24 620103.52 N 70.35588969 W 149.02460610 3683.68 30.27 87.05 3411.53 1216.00 19.64 1221 .17 0.27 5980709.21 620150.41 N 70.35589572 W 149.02422502 3776.79 29.47 89.82 3492.27 1262.11 20.92 1267.51 1.71 5980711 .22 620196.72 N 70.35589920 W 149.02384871 3870.20 28.88 89.14 3573.83 1307.47 21.33 1313.04 0.72 5980712.35 620242.24 N 70.35590030 W 149.02347898 3963.46 28.85 88.86 3655.50 1352.29 22.12 1358.06 0.15 5980713.85 620287.23 N 70.35590242 W 149.02311346 .---- 4056.89 28.22 90.92 3737.59 1396.77 22.21 1402.68 1.25 5980714.66 620331.84 N 70.35590266 W 149.02275110 4149.50 28.39 90.50 3819.12 1440.59 21.67 1446.59 0.28 5980714.81 620375.75 N 70.35590115 W 149.02239455 4242.84 28.06 89.66 3901.36 1484.61 21.61 1490.73 0.55 5980715.45 620419.88 N 70.35590095 W 149.02203611 4335.30 28.00 89.08 3982.98 1527.89 22.08 1534.18 0.30 5980716.61 620463.31 N 70.35590223 W 149.02168331 4427.93 27.85 92.74 4064.83 1571.17 21.40 1577.53 1.86 5980716.62 620506.67 N 70.35590034 W 149.02133126 4520.75 29.62 93.47 4146.22 1615.78 18.97 1622.09 1.94 5980714.90 620551.26 N 70.35589369 W 149.02096946 4614.52 30.09 93.59 4227.54 1662.45 16.10 1668.68 0.51 5980712.77 620597.88 N 70.35588581 W 149.02059115 4708.76 29.40 93.48 4309.36 1709.20 13.22 1715.35 0.73 5980710.62 620644.58 N 70.35587790 W 149.02021221 4802.23 29.16 92.98 4390.89 1754.91 10.64 1760.99 0.37 5980708.77 620690.26 N 70.35587083 W 149.01984160 S-109PB1 ASP Final Surveys.xls Page 2 of 4 1/29/2003-5:24 PM Grid Coordinates Geographic Coordinates Station 10 MO Incl Azim TVD vSec waS EI-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (01100ft) (ftUS) (ftUS) 4894.58 30.47 92.35 4471.02 1800.80 8.51 1806.85 1.46 5980707.37 620736.15 N 70.35586498 W 149.01946917 4987.70 32.04 92.91 4550.62 1849.09 6.29 1855.12 1.71 5980705.92 620784.43 N 70.35585888 W 149.01907728 5079.93 32.23 92.32 4628.72 1898.12 4.05 1904.12 0.40 5980704.46 620833.47 N 70.35585273 W 149.01867935 5173.57 32.51 91.67 4707.81 1948.21 2.31 1954.23 0.48 5980703.51 620883.59 N 70.35584793 W 149.01827251 5267.45 32.68 91.00 4786.90 1998.71 1.13 2004.78 0.42 5980703.13 620934.15 N 70.35584468 W 149.01786197 5360.61 33.06 91.10 4865.15 2049.18 0.20 2055.34 0.41 5980703.01 620984.71 N 70.35584211 W 149.01745148 5452.16 31.36 90.80 4942.61 2097.89 -0.61 2104.13 1.87 5980702.97 621033.50 N 70.35583986 W 149.01705531 5544.57 29.16 91.74 5022.42 2144.38 -1.63 2150.68 2.44 5980702.69 621080.06 N 70.35583703 W 149.01667730 5638.06 29.00 92.91 5104.13 2189.79 -3.47 2196.08 0.63 5980701.57 621125.48 N 70.35583197 W 149.01630865 5730.76 28.94 91.55 5185.23 2234.65 -5.22 2240.94 0.71 5980700.54 621170.36 N 70.35582716 W 149.01594437 5824.05 28.41 90.61 5267.08 2279.34 -6.07 2285.70 0.75 5980700.40 621215.12 N 70.35582481 W 149.01558095 .--, 5918.28 29.18 92.36 5349.66 2324.66 -7.25 2331.06 1.21 5980699.94 621260.50 N 70.35582153 W 149.01521256 6013.07 29.28 92.69 5432.38 2370.92 -9.29 2377.31 0.20 5980698.63 621306.76 N 70.35581592 W 149.01483707 6106.73 28.75 92.50 5514.28 2416.33 -11.35 2422.69 0.57 5980697.29 621352.17 N 70.35581026 W 149.01446857 6200.27 29.01 94.62 5596.19 2461.49 -14.16 2467.77 1.13 5980695.20 621397.28 N 70.35580255 W 149.01410250 6293.77 30.05 95.18 5677.54 2507.57 -18.10 2513.69 1.15 5980691.99 621443.25 N 70.35579174 W 149.01372968 6386.86 29.85 94.61 5758.20 2554.05 -22.06 2559.99 0.37 5980688.76 621489.61 N 70.35578086 W 149.01335369 6480.48 29.24 94.64 5839.65 2600.21 -25.78 2606.01 0.65 5980685.77 621535.67 N 70.35577065 W 149.01298006 6574.24 30.56 95.02 5920.93 2646.95 -29.72 2652.58 1.42 5980682.57 621582.30 N 70.35575985 W 149.01260191 6667.36 33.63 96.73 5999.81 2696.40 -34.82 2701.78 3.44 5980678.26 621631.57 N 70.35574588 W 149.01220239 6760.54 36.27 96.55 6076.18 2749.73 -40.99 2754.80 2.84 5980672.93 621684.67 N 70.35572898 W 149.01177191 6853.79 36.28 94.28 6151.36 2804.89 -46.19 2809.71 1.44 5980668.60 621739.66 N 70.35571470 W 149.01132599 6947.19 36.67 90.57 6226.47 2860.36 -48.53 2865.17 2.40 5980667.14 621795.14 N 70.35570825 W 149.01087572 7039.47 38.96 89.72 6299.37 2916.77 -48.66 2921.74 2.54 5980667.91 621851.70 N 70.35570783 W 149.01041635 7132.00 42.03 90.96 6369.72 2976.70 -49.04 2981.82 3.43 5980668.48 621911.77 N 70.35570673 W 149.00992852 7224.51 44.93 93.69 6436.85 3040.29 -51 .66 3045.40 3.73 5980666.87 621975.38 N 70.35569950 W 149.00941223 ~ 7317.65 51.57 97.07 6498.85 3109.71 -58.28 3114.51 7.62 5980661.35 622044.59 N 70.35568135 W 149.00885105 7410.67 57.19 100.13 6553.01 3185.07 -69.65 3189.22 6.61 5980651.17 622119.46 N 70.35565020 W 149.00824444 7504.34 61.14 101 .23 6601.01 3265.01 -84.57 3268.24 4.34 5980637.51 622198.70 N 70.35560935 W 149.00760288 7597.32 63.08 101.70 6644.50 3346.56 -100.90 3348.77 2.13 5980622.46 622279.48 N 70.35556462 W 149.00694899 7629.92 63.66 101.54 6659.12 3375.48 -106.77 3377.32 1.83 5980617.04 622308.11 N 70.35554855 W 149.00671723 7660.49 63.33 101.09 6672.76 3402.64 -112.14 3404.14 1.70 5980612.10 622335.01 N 70.35553386 W 149.00649942 7690.55 63.33 101.48 6686.25 3429.31 -117.40 3430.49 1.16 5980607.26 622361.43 N 70.35551946 W 149.00628555 7723.59 63.83 101.34 6700.95 3458.68 -123.25 3459.49 1.56 5980601.87 622390.52 N 70.35550344 W 149.00605005 7760.87 64.00 101.89 6717.34 3491.90 -129.99 3492.29 1.40 5980595.65 622423.42 N 70.35548498 W 149.00578377 S-109PB1 ASP Final Surveys. xis Page 3 of 4 1/29/2003-5:24 PM Grid Coordinates Geographic Coordinates Station 10 MO Inel Azim TVO VSec NI-S EJ-W DLS NQrthing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 7870.48 71.14 108.81 6759.19 3591.20 -156.93 3589.81 8.74 5980570.27 622521.35 N 70.35541127 W 149.00499201 7900.45 73.96 109.00 6768.17 3618.88 -166.19 3616.85 9.46 5980561.44 622548.53 N 70.35538593 W 149.00477244 7931.45 76.70 108.73 6776.02 3647.92 -175.89 3645.23 8.86 5980552.20 622577.06 N 70.35535941 W 149.00454207 7963.02 79.75 105.93 6782.47 3678.04 -185.08 3674.73 12.99 5980543.47 622606.70 N 70.35533423 W 149.00430259 7995.02 80.00 107.57 6788.09 3708.82 -194.16 3704.89 5.09 5980534.87 622637.00 N 70.35530940 W 149.00405769 8026.01 81.56 108.17 6793.06 3738.57 -203.55 3734.00 5.39 5980525.95 622666.25 N 70.35528372 W 149.00382134 8057.55 83.73 106.68 6797.10 3769.05 -212.91 3763.85 8.34 5980517.06 622696.24 N 70.35525809 W 149.00357906 8088.58 83.91 1 07.1 0 6800.44 3799.17 -221.88 3793.36 1.44 5980508.57 622725.89 N 70.35523356 W 149.00333941 8122.03 85.77 105.61 6803.45 3831.76 -231.25 3825.33 7.12 5980499.70 622758.00 N 70.35520790 W 149.00307990 8151.56 88.89 105.12 6804.82 3860.72 -239.07 3853.77 10.71 5980492.34 622786.56 N 70.35518651 W 149.00284900 8183.00 90.23 1 05.44 6805.06 3891.60 -247.35 3884.10 4.37 5980484.54 622817.01 N 70.35516384 W 149.00260278 '-'" 8214.64 90.13 1 04.36 6804.97 3922.71 -255.49 3914.67 3.43 5980476.89 622847.71 N 70.35514157 W 149.00235455 8244.48 89.89 104.74 6804.96 3952.09 -262.98 3943.56 1.53 5980469.85 622876.70 N 70.35512105 W 149.00212005 8277.31 90.92 105.92 6804.73 3984.32 -271.66 3975.21 4.76 5980461.68 622908.49 N 70.35509729 W 149.00186302 8307.69 92.29 106.96 6803.88 4014.03 -280.26 4004.34 5.68 5980453.55 622937.75 N 70.35507377 W 149.00162656 8339.37 92.26 1 07.40 6802.62 4044.90 -289.61 4034.58 1.38 5980444.68 622968.13 N 70.35504818 W 149.00138104 8369.44 90.03 106.90 6802.02 4074.22 -298.47 4063.31 7.60 5980436.27 622997.00 N 70.35502392 W 149.00114784 8393.81 89.72 106.74 6802.07 4098.02 -305.53 4086.63 1.42 5980429.59 623020.43 N 70.35500461 W 149.00095846 8446.50 89.72 106.74 6802.33 4149.50 -320.71 4137.09 0.00 5980415.22 623071.11 N 70.35496307 W 149.00054884 ~. S-1 09PB 1 ASP Final Surveys.xls Page 4 of 4 1/29/2003-5:24 PM Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: 8eth Well Job# Log Description S-109 cJO;:)"rlL/~" 23043 US IT PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECE'VED FEB 1 4 2003 Alaaka Oil & G8S cons. eornrniseicn Þltch0rage NO. 2663 02113/03 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Date BL 01/15/03 Aurora Sepia Color CD Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TIN: Beth Recei~Y: ~d)ayJJ ---- qOd-àt/5 ) I) ¡ MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No S-109 PB1 Date Dispatched: 30-Jan-03 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 Received By: ~ G. (b¡p~ase sign and return to: RECEIVED James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery Y1.1, Dee '97 FEB 03 2003 Alaaka œ & Gu Cons. Commieeion AnctICIIge ) ) ~-c)tj5 MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No 8-1 09 Date Dispatched: 29-Jan-03 I nstallation/Rig Nabors 9E8 Dispatched By: Nate Rose Data No Of Prints No of Floppies 8u Neys 2 ~. f n Please sign and return to: Received By: ~ Ll1! 00r-- LWD Log Delivery V1.1, Dec '97 RECEIVED James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com FEB 03 2003 Al8Ika Oñ & Gel Cons. ConvnieIim AndIcnge Re: [Fwd: FW: S-lI5: gas in surface hole] ) ) Subject: Re: [Fwd: FW: 8-115: gas in surface hole] Date: Mon, 30 Dec 2002 13:11:23 -0900 From: Robert Crandall <Bob_Crandall@admin.state.ak.us> Organization: DOA-AOGCC To: Winton Aubert <Winton_Aubert@admin.state.ak.us> CC: Daniel T Seamount JR <dan_seamount@admin.state.ak.us>, Camille 0 Taylor <cammy_taylor@admin.state.ak.us>, Michael L Bill <mike _ bill@admin.state.ak. us> Winton: 8-115 was drilled with spud mud and a density slightly more than water (est 8.5 lb/gal). The data BPX submitted consisted of a "calibrated gas detection log". The data is recorded in units and here 50 units equals 1% gas. The maximum gas show is approximately 80 units through a thin zone at the base of the permafrost. this approaches 2% gas in the mud. This type of gas concentration does not represent a drilling hazard. I recommend approval of diverter waivers on S-pad. RPC Winton Aubert wrote: > > Please review the attached. We should inform BP of our decision by > early PM. > > Thanks, > Winton > > ------------------------------------------------------------------------ > > Subject: FW: S-115: gas in surface hole > Date: Mon, 30 Dec 2002 13:21:25 -0600 > From: "Crane, Lowell R" <CraneLR@BP.com> > To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> > CC: "Stanley, Mark J (ANC) " <StanleMJ@BP. com>, > "Tirpack, Robert B" > < TirpacRB@BP. com>, > "Franks, James D" <FranksJD@BP.com> > > «S-115 Surface Hole Gas Units. ZIP» > > Winton, > > We did receive the S-109 Permit to Drill on Friday afternoon. I would like > to thank those involved for the timely approval and delivery of the permit > over the holidays. > > Per our discussion on Friday, I would now like to follow up on the diverter > waiver issue. > > Our Aurora Geologist, Jim Copen, has reviewed the attached data from the > S-115 surface hole and has concluded similarly to the field Geologist and > the BP supervisory personnel on 9ES that no accumulation of gas or hydrates > were encountered while drilling this surface hole. The maximum gas units > encountered were approximately 70u at the base of the permafrost. (When > viewing this file keep in mind this data was collected every 2 seconds. > When gas logs are produced in the field, the data that is plotted is > typically 10 second averages.) > > I also followed up with our Company Representative currently on ges > concerning the difficulty of rigging the diverter on S-109. He agrees that > a diverter can be rigged. However, it will require a significant effort > including crane work and perhaps some excavation to install the diverter > line beneath the existing production flowlines. The comment I recall from > our conversation on Friday of it being "no big deal" to install a diverter > on S-109 seems to misrepresent the Tool Pusher's and Company > Representative's concerns for type of work required for the job. They very 10f2 12/30/2002 1 :20 PM Re: [Fwd: FW: S-115: gas in surface hole] ) ) > much would like us to continue to pursue obtaining a diverter waiver. > > It is anticipated that 9ES will be released from S-115 tonight at > approximately 1800 hours at which time the rig will begin moving to S-109. > Your prompt reconsideration for our request for a diverter waiver while > drilling the S-109 surface hole would be appreciated. > > Thx, > > Lowell > > -----Original Message----- > From: Copen, James D > Sent: Monday, December 30, 2002 9:14 AM > To: Crane, Lowell R > Subject: S-115: gas in surface hole > > Having reviewed the gas data from surface hole of well S-115, I see no > evidence of significant gas/gas hydrate accumulation. The maximum gas > reading is 50-70 units at a depth of 2150'MD. > > Jim Copen - Geologist > GPB / Satellites > (907) 564-5162 / Rm. 649 > Mobile: (907) 440-8011 > > > > 8-115 Surface Hole Gas Units. ZIP (application/x-zip-compressed) ------------------------------------------------------------------------ Name: S-115 Surface Hole Gas Units. ZIP Type: Zip Compressed Data > Encoding: base64 20f2 12/30/2002 I :20 PM FW: 8-115 Gas ') Subject: FW: S-115 Gas Date: Fri, 27 Dee 2002 11 :39:59 -0600 From: "Crane, Lowell R" <CraneLR@BP.eom> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> Winton, Tania is the onsite geologist for this well. By all accounts, there was no notice of any gas while drilling the S-115 surface hole. I confirmed that the gas data will not be accessible until tonight. LRC -----Original Message----- From: Maskell, Dick Sent: Friday, December 27, 2002 7:34 AM To: Crane, Lowell R Subject: FW: S-115 Gas This was all she could say about absence of gas and/or hydrates on S-115. We also didn't see any evidence of gas based on our observations on the rig floor and in the pits when we were drilling surface hole. Dick Maskell BPX Drilling Rep Nabors 9ES 1-907-659-4831 maskelcr@bp.com <mailto:maskelcr@bp.com> -----Original Message----- From: Cunningham, Tania M (Petrotechnical) Sent: Thursday, December 26, 2002 3:57 PM To: Maskell, Dick Subject: S-115 Gas Dick, Per your question concerning gas in the surface hole for S-115-- all information I have on hand indicates there was no evidence of appreciable gas or hydrates while drilling the surface hole. Tania ~'-.. Q'.""i.I=:.f, . (Æ^' ,1~r r, -[.::::! ~ I il ¡"~ ¡r.o ì '.' ' ¡ I \,.~"i d u· u 1: rru=\\ r? : I ¡ I L, \..~ Lor J !Æ~~~~!Æ ) A"~ASKA OILAlWD GAS CONSERVATION COMMISSION Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, Alaska 99519 FRANK H. MURKOWSKI, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit S-l 09 BP Exploration (Alaska), Inc. Permit No: 202-245 Surface Location: 4466' NSL, 4498' WEL, Sec. 35, T12N, R12E, UM Bottomhole Location: 202' NSL, 2491' EWL, Sec. 25, T12N, R12E, UM Dear Mr. Crane: Enclosed is the approved application for pennit to drill the above referenced development well. This pennit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ð~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION ,.,. DATED this 27-day of December, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,'.. STATE OF ALASKA \ ALASKA L.~)AND GAS CONSERVATION COMMI~....JON PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool ~ Plan KBE = 64.4' Prudhoe Bay Field I Aurora 6. Property Designation Pool (Undefined) ADL 028257 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 5-109 ý" 9. Approximate spud date 12/27102 ./ Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 11530' MD I 6824' TVD o 17. Anticipated pressure {sJS 20 AAC 25.035 (e) (2)} 91 Maximum surface 2734 psig, At total depth (TVD) 6760' I 3410 psig Setting Depth T OD Bottom MD TVD MD TVD Surface Surface 109' 109' Surface Surface 31151 2858' Surface Surface 7727' 6714' 7577' 6585' 9227' 6780' 9227' 6780' 11530' 6824' II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Prepared By Name/Number: Terrie Hubble, 564-4628 ng is true ~ 5~rect to the best of my knowledge Á. ~ Title Senior Drilling Engineer Date /2.- /7......;) L 'Coij"issioD ,~.ÖnJY:' 1 a. Type of work II Drill 0 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4466' NSL, 4498' WEL, SEC. 35, T12N, R12E, UM At top of productive interval 4339' NSL, 980' WEL, SEC. 35, T12N, R12E, UM At total depth 202' NSL, 2491' EWL, SEC. 25, T12N, R12E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028279, 2789' MD S-102 is 6' away at 500' MD 16. To be completed for deviated wells Kick Off Depth 275' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina Weiaht Grade Couplina 42" 34"x20" 91.5# H-40 Weld 9-5/8" 40# L-80 BTC 7" 26# L-80 BTC-M 4-1/2" 12.6# L-80 IBT 4-1/2" 12.6# L-80 IBT 12-1/4" 8-314" 6-1/8" 6-1/8" Lenath 80' 3087' 7699' 1650' 2303' 19. 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 Size Length Cemented Structural Conductor Surface Intermediate Production Liner RECEIVED DEC 17 2002 Perforation depth: m~~Uf~U& Gas Gons. CommiSSiQil WJtiJ\Ø ~ An horana true vertical rumC ì!J 20. Attachments \t.l,<.;,,~,tÞi·20,tl.: f:~'''è;.--' 1! 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantitv of Cement (include staae data) 260 sx Arctic Set (Approx.) 594 sx PF 'L', 229 sx Class 'G' 310 sx Litecrete, 102 sx Class 'G' 254 sx Class 'G' Uncemented Slotted Liner ./ MD TVD Permit Number 20 z. - 2. 7'..5 Conditions of Approval: ~~mval qate. J~d.7/0:3- Mud Log ~equired See cover letter for other reQuirements DYes t8:I No Directional Survey Required ø Yes 0 No o 4K D5K D10K D15K 0 3.5K psi for CTU API Number 50- 029- Z3/?S Samples Required 0 Yes 181 No Hydrogen Sulfide Measures 0 Yes l81 No Required Working Pressure for BOPE 0 2K 0 3K Other: "R:~..t-~ÞE ft:'" 4~CC eÇ.~ . ORIGINAL SIGNED BY M t.., Bill Commissioner by order of the commission Approved By Form 10-401 Rev. 12-01-85 Date / J ~.}, -7/0 d Su~~it InlrriPlicate 8-115 Gas Log ) Subject: 8-115 Gas Log Date: Thu, 26 Dec 2002 19 :43 :23 -0600 From: "Crane, Lowell R" <CraneLR@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "NSU, ADW Drlg Rig ges" <NSUADWDrlgRigges@BP.com>, "Franks, James D" <FranksJD@BP.com>, "Magee, D Neil" <MageeDN@BP.com>, "Tirpack, Robert B" <TirpacRB@BP.com> Winton, Upon further investigation it appears that the surface hole gas data was collected from S-115. The Epoch service hand will be on the Slope Friday evening and he must download the data for us to be able to access it. We are not collecting the gas data real time. Once he downloads the data from the Rig Watch system, we'll forward the file to you ASAP, but it certainly will not be until after your offices close on Friday evening. S-109 spud, pending permit approval, is anticipated to be this Sunday. After you talk to the Commissioners tomorrow morning, please give me a call @ 564-4089 (w) or 240-8054 (c). Thx, LRC 8-109 Diverter Waiver ') Subject: S-109 Diverter Waiver Date: Thu, 26 Dee 2002 19:05:45 -0600 From: "Crane, Lowell R" <CraneLR@BP.eom> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Franks, James D" <FranksJD@BP.eom>, "Tirpaek, Robert B" <TirpaeRB@BP.eom>, "Magee, D Neil" <MageeDN@BP.eom>, "NSU, ADW Drlg Rig ges" <NSUADWDrlgRigges@BP.eom> Winton, No gas log was obtained while drilling the surface hole on 8-115. The rig was working under the pretense that they needed to get everything up and working on 8-115 in order to obtain a gas log on 8-109, an obvious miscommunication between Anchorage and the 810pe. My understanding is that the gas log was requested by the AOGCC because no one, neither BP nor the AOGCC, could find a surface hole gas log from any 8 Pad well. Even though we have evidence in our files that one had been obtained in a previous well, no log has been located. Nonetheless, the 9E8 gas monitoring equipment is now up, operational and ready for 8-109. I have asked the field to send in a geologic summary of the 8-115 surface hole especially including any information concerning any gas encountered. I've also asked that they send in a digital photo of the 8 Pad congestion adjacent to the 8-109 slot that will make a diverter installation difficult. I'm not sure there is enough light up there to get a useable photo in time to help us with the request for an 8-109 diverter waiver however. I will try to get this information to you A8AP so you'll have it when your go over the 8-109 APD with the Commissioners in the morning. I will also suggest that the rig supervisor contact the 810pe AOGCC Inspector and discuss what might be an acceptable layout of a diverter line in our situation just in case an 8-109 diverter waiver is not possible. Hope your Dr. appointment goes well. We'll visit in the morning. Lowell i~ ) ... bp ,\If.'II, ......~ ~~. .~~ i~. .'~$¡\. ) To: Winton Aubert, AOOCC Date: Dec. 13,2002 From: Rob Tirpack Subject: Dispensation for 20 AAC 25.035 (c) on 8-109 BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, support the rationale for the request. To date, none of the 40-plus Ivishak wells at S-pad, nor the recent Aurora/Polaris wells have experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. The first ten surface holes for the AuroraJPolaris development were drilled no deeper than the shale underlying the SV-l sands; S-109 is planned to TD in the shallower SV-3 shale, as did the most recent wells (apart from $-106 where a diverter was installed). The shale underlying the SVl is the deepest planned surface casing setting depth for future pad development wells. This casing point is ±700' TVD above the U gnu horizon. ./ The shallowest and most recent RFT points recorded in the area are from S-201, recording a pore pressure of 1,423psi at 3,175' TVDss (8.6 ppg EMW) and not exceeding 8.7 ppg EMW above 3700' TVDss. S-109 is planned to reach 9.5 ppg mud weight before TD at 2,794' TVDss. If the wavier can not be granted, work is in progress to install the diverter line with several direction changes. Discussions between Lou Oramaldi and the Nabors ges rig team have led to the planned installation of "Targeted T's" for the direction changes in the diverter line. It is BP's preference to pursue the diverter wavier rather than install the diverter line with direction changes. / Your consideration of the waiver is appreciated. ~~ Rob Tirpack OPB Rotary Drilling Engineer 564-4166 ) ) I Well Name: 18-109 Drill and Complete Plan Summary I Type of Well (service / producer / injector): I Producer Surface Location: As-B u i It Target Location: Top Kuparuk Bottom Hole Location: x = 618,929.81' Y = 5,980,670.18' 4466'F8L,4498'FEL,Sec.35,T12N,R12E X = 622,450.02' Y = 5,980,600' 4339'FSL,980'FEL,Sec.35,T12N1R12E X = 625,900.00' Y = 51981,800.00' 202'FSL,2789'FEL,Sec.25,T12N1R12E " I AFE Number: I AUD5M00461 fEstimated Start Date: 112/27/2002 I I Ria: I Nabors 9ES ;- I Operatina days to complete: 126.5 I MD: 111530' I 1 TVD: 16824' 1 I GL: 135.9' I 1 RKB: 128.5' 1 1 KBE: 164.4' I Well Desian (conventional, slim hole, etc.): I Ultra slimhole - Horizontal I Objective: 1 Kuparuk Formation Mud Program: 12-1/4" Surface Hole (O-3115'): Fresh Water Surface Hole Mud Densitv Viscosity Yield Point Tau 0 API FL PH (ppg) (seconds) (lb/100ft£) (mls/30min) Initial 8.5- 9.2 250-300 50 - 70 >20 15-20 8.5-9.5 below Permafrost 9.0 - 9.5 200 30 - 45 >15 <8 8.5-9.5 interval TO 9.5 max 150-200 20 - 35 >15 <8 8.5-9.5 8-3/4" Intermediate Hole (3115' - 7727'): Fresh Water LSND Interval Density Tau 0 YP PV pH API HTHP (ppg) Filtrate Filtrate Upper Interval 9.7 I 4-7 27 -32 1 0-15 8.5-9.5 6-10 <5 HRZ to TO 10.3 3-7 17-25 1 0-15 8.5-9.5 4-6 <10 by HRZ 6-1/8" Production Hole (7727' - 11530'): KCI-CaC03, Baradril-N Interval Density Chlorides YP PV MBT LG Solids HTHP (ppg) Filtrate Kuparuk 10.0 22,000 22-30 18-27 0 <1 <10 8-109 Permit to Drill ') ') Formation Markers: MD 1585' 20711 2354' 2571' 3001' 316T 3555' 39411 4004' 41111 4332' 4953' 5269' 5505' 5635' 5966' 7358' 754T 772T 772T 7815' 9342' TKUP@TD11530'6770' ~HYdro)arbon Bearing, 9.7 ppg *A kick occurred at S-200PB1 in UG4a sands that required .3-1fJ~Š ppg MW to control. *A thin lower UG4a coal at S-201 showed an RFT of 10.1 P W. Formation Tops SV6 Base Permafrost SV5 SV4 SV3 SV2 SV1 UG4 UG4A UG3A UG3 UG1 Ma - Top Schrader Schrader Bluff N Schrader Bluff 0 Base SBlTop Colville CM1 THRZ Kalubik (BHRZ) TKUP LCU (top A6 sand) TKA4 Directional: Ver. Anadrill P5; Slot #11 KOP: 275' Maximum Hole Angle: Close Approach Wells: Survey Program: 8-109 Permit to Drill TVDss 1521' 1875' 2116' 23151 26941 2840' 3182' 3522' 357T 36711 3866' 4413' 4691' 4899' 5013 5305 6455 6560 6650 6650 66901 6718' Estimated Pore Pressure 8.2 ppg 8.2 ppg 8.2 ppg 8.2 ppg 8.7 ppg 8.7 ppg 8.7 ppg 8.7 ppg Hydrocarbon Bearing, 9.0* ppg Hydrocarbon Bearing, 9.0 ppg Hydrocarbon Bearing, 8.6 ppg Hydrocarbon Bearing, 8.6 ppg Hydrocarbon Bearing, 8.6 ppg Hydrocarbon Bearing, 8.6 ppg Hydrocarbon Bearing, 8.6 ppg Hydrocarbon Bearing, 8.6 ppg 8.6 ppg 8.6 ppg 9.7 ppg 9.7 ppg Hydrocarbon Bearing, 9.7 ppg Hydrocarbon Bearing, 9.7 ppg \'Q.~ -"' 600 in the Intermediate Interval 910 in the Production Interval S-102 and S-110 fail BP's guidelines for close approach. / Each well will be shut-inl tubing tail plugs installed, bleed of pressure, fluid packed, and freeze protected prior to the rig arriving. S-12 passes BP's guidelines for close approach when minor risk based. This well was PAId in 10/84. Gyro: 0 - 1,3001 Standard MWO surveys+IFR+MS: 113001 to TO ') ') Logging ProQram: Surface Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / RES / PWD Open Hole: None Cased Hole: USIT - after Production Liner is installed Drilling: MWD / GR / Res / Dens / Neu / Inc at bit Open Hole: None Cased Hole: None Intermediate Hole CasingITubing Program: Hole Csgl WtlFt Grade Conn Length Top Btm Size Tbg O.D. MDrrVD MDrrVD bkb 42" Insulated 91.5# H-40 W7P 80' GL 109/109 34"x20" ~/ 12-1/411 9-5/8" 40# L-80 BTC 30871 GL 31151/2858' 8-3/4" 7" 26# L-80 BTC-m 7699' GL 7727'/6714' 6-1/8" 4-1/2"-Solid 12.6# L-80 IBT 1650' 7577'/6585' 9227'/6780' 6-1/811 4-1/2" -Slotted 12.6# L-80 IBT 2303' 92271/6780' 115301/68241 Tubing 4-1/2" 12.6# L-80 TCII 7549' GL 7577'/6585' Integrity Testing: Test Point Depth Surface Casing Shoe 20' min from shoe Intermediate Casing Shoe 20' min from shoe Test Type EMW LOT 12.3 ppg for a 92 bbl kick tolerance FIT 12.0 ppg - Infinite kick tolerance 8-109 Permit to Drill l ') ) Cement Calculations: The following surface and production cement calculations are based upon a single stage job. Casinq Size 19-5/811 Surface I Basis: Lead: Based on 2071' of annulus in the permafrost @ 250% excess and 476' of open hole from top of tail slurry to base permafrost @ 300/0 excess. Lead TOG: To surface Tail: Based on 5681 MD open hole volume + 30% excess + 80' shoe track volume. Tail TOG: At ....2547' MD /"'~') Total Cement Volume: Lead 439 bbl I 2465 f.~~ I .'~-:!,'/sks of Halliburton Permafrost L at 10.7 ppg and 4.1 < ~sk. Tail 47 bbl I 264 fe ~ Isks of Halliburton Premium 'G' at 15.8 ppg and 1. cf/sk. Casinq Size 17" Intermediate 1 Basis: Lead: Based on 3786' of open hole + 30% excess: From 500' MD above the top of the UG4A formation to top tail slurry. Lead TOG @ 3441' MD Tail: Based on 500' MD of open hole + 300/0 excess + 801 shoe track volume. Tail TOG @ 7227' MD (5001 above 7" shoe) ...·-1 Total Cement Volume: Lead 132 bbl I 741 fe 16,c1skS of Litecrete at 12.0 ppg and 2.39 cf/sk ,-:;:.-, \ Tail 21 bbl 1118 fe ~O?t~kS of Premium 'GI at 15.8 ppg and 1 .16 cf/sk. -:?" Casinq Size 14-1/21' Intermediate I Basis: Tail: Based on 1650' of open hole + 50% excess + 150' liner lap + 2001 above lap: From EGP depth to top of liner. Tail TOe@7577'MD(linertop) ~".P"""'~ Total Cement Volume: Tail 52 bbl I 292 fel'2 sks of Halliburton Premium 'GI at 15.8 ppg and 1-:' cf/sk. 8-109 Permit to Drill ') ) Well Control: Surface hole will be drilled with diverter. The intermediate and production holes will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the information listed below the BOP equipment will be tested to 4000 psi. Diverterl BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 3410 psi (9.7 ppg EMW @ 67601 TVDss - KUP) 2734 psi ~ su rface (based on a full column of gas @ 0.10 psi/ft) 4000 psi /' 8.6 ppg filtered seawater / 6.8 ppg Diesel · Planned BOP test pressure: · Planned completion fluid: Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class" wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. H2S: · H2S readings are listed below. S-Pad is not designated as a H2S pad, however Standard Operating Procedures for H2S should be followed at all times. #1 Closest SH L #2 Closest SHL #1 Closest BH L #2 Closest BH L Max Reading on Pad Well Name S-1 02 S-11 0 S-12A S-14 S-40 H2S level 10 ppm 10 ppm 40 ppm 10 ppm 70 ppm 8-109 Permit to Drill ') ') DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor was installed in November 2002. 1. Weld a FMC landing ring for the FMC Ultra Slim hole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Shut-in S-102 and S-11 O. Set tubing tail plugs, bleed all pressures, fluid pack tubing and lA, and freeze protect. Remove well houses. Rig Operations: 1. MIRU Nabors 9ES on Slot #11. / 2. Nipple up diverter spool and riser. PU 411 DP as required and stand back in derrick. ./ 3. MU 12-1/411 drilling assembly with MWD/GR and directionally drill surface hole to 3115 'MD/2858' TVD. Actual TO will be ap~oximately 100' TVD below the SV3 sands (see Anadrill directional plan). 4. Run and cement the 9-5/811, 40# surface casing back to surface. A Tam port collar will be run at 1000' as a contingency on the chance that cement returns are not seen at the surface. 5. NO diverter spool and NU casing I tubing head. NU BOPE and test to 4000 psi. r" 6. MU 8-3/411 drilling assembly with MWD/GR/PWD and RIH to float collar. Test the 9-5/811 casing to 4000 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.7 ppg LSND drilling fluid. Drill new formation to 20' below 7- 5/811 shoe and perform Lea~,pff Test. 8. Drill ahead to 7727' MD/6714' TVD following the directional and mud programs. Actual TO will be at the base of the HRZlTop of Kuparuk. Condition hole for running casing and POOH. /' 9. Run and cement the 711 production casing as required from TO to 500' above UG4a. Displace the casing with mud during cementing operations and freeze protect the 711 x 9-5/811 annulus as required. 10. MU 6-1/811 drilling assembly with triple combo real time LWD and RIH to float collar. Test the 711 casing to 4000 psi for 30 minutes. 11. Drill out shoe joints and displace well to 10.0 ppg Baradril-N mud. Drill new formation to 20' below 711 shoe and perform For~tion Integrity Test. 12. Drill ahead to 11,530' MD/6824' TVD following the directional and mud programs. Actual TO will be at the Top of Kuparuk at the toe of the hor;9F1tal. Condition hole for running the liner and POOH. 13. Run and Bonzai cement the 4-1/211 solid and slotted liner. ECP depth to be determined from LWD logs. Release from the I~t and displace to 10.0 brine. 14. RU e-line. Run USIT cement evaluation log from top of liner to top of cement. 15. Run the 4-1/2111 12.6#, L-80 gas lift completiofl)issembly. Set packer. 16. Test the tubing and annulus each to 4000 psi for 30 minutes. Release tubing pressure and shear RP valve. 17. Install TWC and test from below to 1000 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 18. Freeze protect the well to -2200' with diesel and secure the well. 19. Rig down and move off. / S-109 Permit to Drill ') )- 8-109 Drilling Program Job 1: MIRU Hazards and Contingencies ~ 8-Pad is not designated as an H2S site. Review H28 table above. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. ~ The closest surface location will be 8-102 and 8-110, which are -15' wellhead to wellhead. Both wells will be shut-in with tubing tail plugs, fluid packed, and freeze protected. ~ Check landing ring height on 8-109, the BOP nipple up may need review. Reference RPs .:. "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" II. .\!LmmlIllII11I11mmllm\. -;m!lmmm~lIIlIltm:'~111ImWUlum:;- - .,1.;:: I \:LmWlml~ ;IUIT~lalllall!- .ml1. JUmmmLI. J I. .... ""'''T _~ v.t ~mm""_UI'~m_i' . .... )t""'" ,I''V..''''..··'','_''L ,mmll'''ImLm__I.1. .1. .1.' Job 2: Drillina Surface Hole Hazards and Contingencies ~ No faults are expected to be penetrated by 8-109 in the surface interval. ~ Drilling Close Approach: 8-102 and 8-110 fail BP anti collision guidelines. 8-102 will have a center to center distance of 6' at 500' and 8-110 will have a center-center distance of 21' at 1150' MD. Both of these wells will be shut-in with tubing tail plugs, fluid packed and freeze protected. A gyro will be required until the interference has dissipated. ~ The 8V4 sand may contain gas hyrdrates, though little or none have been encountered thus far in recent S-pad developments. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation ~ Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" 11111I111" ¡t; :III"T -"--lIn- .1 .1. .1.1. .I,. .1. .1.1. TITI. _1:11..1:111. -u. .1. .UI . -,I. -'--'-IU' :111111I111I1111111.111.11111'1__1 :1--I'I-:I:III~"m'll:m::nll:' I:II_ .1_1.111'__1 '---II-II: --"-11-'--'-- --,-- :I'-Y4."Ul'mmmnlmlll.lmll.III'I:- --I-·:I:~I!'''mlmlll!..r.l. _I. ···"'11'.11.1.1' Job 3: Install Surface Casina Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. Plan 250% excess cement through the permafrost zone and 300/0 excess below the permafrost. A 9-5/8" port collar will be positioned at ±1 OOO'MD to allow a secondary circulation should cement to surface not be achieved. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Halliburton Cement Program" .:. "Surface Casing Port Collar Procedure" 8-109 Permit to Drill ') ') m¡ Mmm;..I) m,-ß!A:ffl)"AI"-":,I,,-,-,-p~m,-"-,I'-"f1mm.-¡!,:mAA-m.:mmm:mmmmm,tt.mA-mm,IIDmw.wm.I.wm)!m.w.I,IJJm.r.;mmmmmmmmmmmn,1ß::.mJß:-J.;.-.-',l.Im:.-",-: J.fflJ AJ;ß;. :.-J.-J.nl~.-;'-.:.wJ,lJ,-.lAAl;.lmIJl'.l.lm.l.l.W)!m.wmmJ,I'wOOmmø;I .IJJ;,;jJ'w!JJ,Wm.l.i.: .l,IL;.I.WJW!JJJJJJJ¡..:nl; J.:J!W,I.I:t;J ;;;JJ ,ImJ.I.I m,l;.I.IAMI.IAAWm,I,I,IJ¡,I,I/,ImmAAb¡.:.w ~,:,I.;m..l.wm"'IA:.:W).:'-,-.-,-.-m.-,-.I.I!AAIß.'.IJ..IÞ#mÞ. Job 4: DrillinQ Intermediate Hole Hazards and Contingencies ~ KICK TOLERANCE: The reservoir pressure of the HRl has been estimated to be 8.6 ppg. Assuming gauge hole, a fracture gradient of 12.3 ppg at the surface casing shoe, 10.3 ppg mud in the hole the kick tolerance is 92 bbls. Þ> No faults are expected to be penetrated by the S-109 in the intermediate hole. Þ> Losses may be encountered when running the production casing string if adequate precautions are not taken including running speed, staging in and optimal mud properties. ~ There are no "Close Approach" issues with the production hole interval of S-109. ~ Differential sticking could be a problem if the drill string is left stationary for an extended period of time across the long permeable section of the Ugnu and Schrader sands. Minimize the time the pipe is left stationary. ~ HRl drilling has been troublesome on offset wells. Follow standard HRl drilling practices. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. IIShale Drilling- Kingak & HRZ" "þ/I ~"'m: 14m,"m'rm:nlll!'IIIIII:lmnl:ml"'m'llIIlm:!llnnmlllll'1IIIIIIIImmll'llml_~lrnlllm'mlmllnm'mlnm n_lmmn_IIL_':mllll!ImllD-II_1_1._ll.þI"-I--'-U\I:\_"",Clml!!llllCnIIlICII"lIIlmmnllmlIIClcml_lmll_lml::llnlr11_all_II_II_:W-_C:!I::CI:~--_1.1::':I-:I__II:a'I-:urml-a'-IUI:--:ml/lClnlmllllln!lllIImnlmmmnllnlmlmlltrmll,II_C'II::I_:IIIIIITal-:'!llIIlmlllll~III__III:,'I Job 6: Install Intermediate CasinQ Hazards and Contingencies Þ> Considerable losses during the running and cementing of the production casing has occurred on L and V-Pad. A casing running program will be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In additionl a LCM pill composed of "Steel Seal" will be placed across the Schrader and Ugnu to help arrest mud dehydration. Þ> Differential sticking could be a problem if the casing is left stationary for an extended period of time across the long permeable section of the Ugnu and Schrader sands. Minimize the time the pipe is left stationary. ~ The 7" production casing will be cemented to 5001 above the top of the UG4A with a single stage- two slurry cement. Getting casing to bottom while maintaining returns is a critical operation. Þ> Ensure the upper production cement has reached at least a 70BC thickening value prior to freeze protecting. After freeze protecting the 9-5/8" x 7" casing outer annulus with dead crude to 2200' MD, the hydrostatic pressure will be 7.7 ppg vs 8.7 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 162 psi underbalance to the open hole Reference RPs .:. Intermediate Casing and Cementing Guidelines .:. Cement Program .:. IIFreeze Protecting an Outer Annulus" S-109 Permit to Drill ') ) ~,~- ¡ ¡;¡~~mmJm.:!mm.¡¡¡mmm ,r,;.¡'Jmmmm, ,-.-,I,I;;¡¡.m)¡·mm¡¡;:.,¡m;:Jm'-M-JA-.-mm'-.-¡', ,-.I.-,I.-,-.-¡.¡m:m~mm!m.I)J¡'J¡¡'~,l)mmmmmmmmM¥WI,I)¡'*'¡';'!!!AI,', l4mmlYm.:m,-,-!o ,~A-,-nm;,I,:,-.-W.-,-AA-,-m,l,lI,l;,-mmmm¡¡.;mmmmlJ,l;mMm;¡.;m;/:JJm.IJ:-!,:.-Al.m;JJ.l.1:;mJ.;.:.-,l,lJU.:JJW.l,WJ,II,I,W;;AAllm;,W,ij.IJI..:m:.D,:JJAAllI,lmw.-m,UmmWJ¡4,I,IJlJlm:..-; mmJ1l;¡mmm',l,JmmWmJmm~-mM'" Job 7: DrillinQ Production Hole Hazards and Contingencies ~ KICK TOLERANCE: The reservoir pressure of the Kuparuk has been estimated to be 9.7 ppg. Assuming gauge hole, a fracture gradient of 12.0 ppg at the surface casing shoel 10.0 ppg mud in the hole the kick tolerance is infinite. ~ One fault is expected to be penetrated by S-109 in the intermediate hole. Throw is estimated at 60'. Lost circulation is expected to be moderate risk. Follow the LC Decision Tree in the event of losses. There is also the risk of drilling out of zone after crossing the fault. Monitor drilling trends and cuttings immediately after crossing the fault. ~ 8-12 fails BP's close approach guidelines in the production hole interval of 8-109. 8-12 was PA'd in 10/84 and has been minor risked. However, all stings of casing were left in place. CIBP's and cement plugs were used to P&A 8-12 back to surface. 8-12 has a center to center distance of 409' at 8265' MD. ~ Differential sticking could be a problem if the drill string is left stationary for an extended period of time. Minimize the time the pipe is left stationary. ~ Seepage losses could be encountered with the long open sands. Follow the LC Decision Tree. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. ~1;}J;,:;'I;~mmm!, ,:m!,rm,lß,lmw¡m¡m,lmAAlwmm"J,I;J!"' ,I.l.rm;¡¡m¡,I)!,I,I,-m!.I.-.:m:;"-;,-,.,, ,:,:J,w;m,I,lmJ.l,I!J,lm,I,I.I,I,D, ,IJ,I~.;¡¡,,~m:m.D.I¡,1~.D¡,\IJ,:mm.I,:m.:.l.IJ,lmm¡.;mmmmn.l),lm~Nmml¡,lmJAA=~J,:,1,Iß,:!;I_I, ,I,:;.I¡,-I,I,~~. . --,I,-,I,I:.I:¡,I:mm-;,-J,lm,Im,"'I;.D.I¡¡ß,I,I';,l,Im¡,aWJ!.i.II.:¡).I);).I,:¡:,-." .)J,:,I,D,-,-:,D,-,~';-!,D.-¡!},D¡,I¡.,I¡¡.}¡mmmm,l¡mm¡!m;;,I,lmlmm;)ml).D.:,I!,IJ¡¡m,I,"';..:':!;-~,I,IUI.l.I}J.I.I.:¡~,I,I,Dm.D.Imm.w.IJ.Iß!,I,I,aJ ;~J.lH Job 9: Install Production Liner Hazards and Contingencies ~ Ensure a minimum hydrostatic equivalent of 10.0 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Loss of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ~ Differential sticking could be a problem if the liner is left stationary for an extended period of time. Minimize the time the pipe is left stationary. Reference RPs .:. uProduction Liner/Casing and Cementing Guidelines" .:. uHalliburton Cement Program" I"' -_,_~, \0.; 11¡;4,11,-,-1¡; -I¡;I¡;FI¡;.-.-,r.-- -nll-'-'" -'-l .,..;., ~ ~.;."'1,~;1Iot,'- -'-I.:,.;,-,T;...· .,IC\ .1... ;11I111-:;:; .._~T,t¡;I¡;--t¡;--t¡;,IO.,;-I¡; -I¡;-,-"'I.I." ¡,;.; "¡'" . ,M; --; .--I'.Il"'.;:- --"".-"':¡- t¡;1,..J\.I,- ,i" \0.; ¡¡.¡.,.--.;' ,.. ...-- -.t¡;---r.--;L:,-........,.¡.,.--I,--;.. Job 9: LOQ Production Hole Hazards and Contingencies ~ Ensure the well is dead and is in optimal condition prior to logging to ensure a successful logging program. Reference RPs .:. Follow Schlumberger logging practices and recommendations. 8-109 Permit to Drill ) ') þJ!'AI;~;;m.I),DJAA:~mmmmmmmmmmm, ÞAAlml}.:,;;,~,I.I~,I!mK-.~ A~;"_,Iml¡·m,-" .,-;¡.:}),:ß,-,-,',-f>,I¡"-, ,-A-¡mm.:!¡m,;m,-¡'A-!Al;"m.-,-m¡;-m».lmm.-AI,-,~I,-A-m~:¡m¡.;¡.;¡.;m,¡,I.I¡m,I;¡;;¡m"I;¡,:.;mm.I,IÞJ,mnm:J'wm.-:l:.W,l.:,1¡.aJm.!.-,':.::m,I.I,I,I.I.W,IL;J;.-m.IJ.Wmm¡mm».I.W¡¡mm;,I.W,;.I'J¡m¡mm,Um,l,:m¡.I.\,I,1.l.I mm,I,I,Im;m;,w,IjJ.I.IJ,i;",L.-;)J.:,IJ.wmJ lA:,IJ,I ; ;..I,I;.,I.I,I,I.I,IJ>,I,I,W,W'!'w¡,;.'mmJ,w.:mmm.l ,w,¥':"'::n.l. Job 12: Run Completion Hazards and Contingencies );> Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. Do not allow well to go underbalanced. );> RP Shear valves have been failing at lower than the 2500 psi differential pressure. When testing annulus maintain no more than a 1500 psi differential. Avoid cycling pressure prior to activating shear valve as this is thought to cause shearing at lower pressures. No failures have been seen since switching over to the DCK shear valve. Utilize the DCK shear valve. );> After freeze protecting, the well will be underbalanced. Ensure the use of double barriers. Reference RPs .:. "Completion Design and Running" .:. "Freeze Protection of Inner Annulus" .. ... -¡''-'-.~."..-.-mm,:.-.-Mil~,'I'I'1'i!4m:;'-'-.I,-.,¡c"wm»;,:'-.,'-,:.lmm,1,l,Imm,W,IJ.',lm,:m,\lm:m,:':..J!.I¡';,I.WÞm,m,lmJ.I.:;,I,I.I,:mJm),:,:mm¡m.l)m,I ,:m,:mm. ,:m,~.;m~m¡,Iß!!,l.Im,l,I,I.Iß.I,:,',_,,-~-¡,~-.-¡.;.!c., ,-:t!, ,I,W~'fI(.m;;.-m'-;,I,l)m,l,l.lm,'.w,:,I,I.I,I,tm.l,l.lmmmmmm,II!,I.I.I,:,I,I.mm',:.I!!,lm.l.I,~I,I.I~m.l. ,;mmmm'-I!, ,~ ,lm~.-m,'-'-,,;.I.-'-,~¡I!,mm,~;.:;,:ml,IßW,l,~).I,I,I,wm,I!,Iß!.I.-"'-)'-,,,,'-.I.'-.l.1,-;,111);;,;),11, Job 13: ND/NU/Release RiQ Hazards and Contingencies );> Close Approach: 8-102 and 8-110 are on 15' well centers. Reference RPs .:. Standard practices apply. .:. Freeze Protection of Inner Annulus. 8-109 Permit to Drill ') ') 5-109 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates have occasionally been encountered near the base of the Permafrost and in the SV sands. No other shallow gas has been reported. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. · S-102 and S-11 0 fail close approach and will be shut-in, fluid packed, and freeze protected. Use gyro until interference dissipates. Intermediate Hole Section: · Expect the Ugnu Intervals to contain hydrocarbons. · All though unexpected, pressure is possible in the UG4A. S-200PB1 required 10.3-10.5 ppg mud to control a kick and S-201 shows a RFT pressure of 10.1 ppg EMW. Subsequent drilling has been done on S pad without problems in the UG4A. · Differential sticking has been experienced in the past. Keep pipe moving at all times. · Lost circulation while drilling has not been problematic at S-Pad. In the event of lost circulation, consult the LCM Decision Tree. · The intermediate hole section will be drilled with a recommended mud weight of 10.3 ppg to ensure shale stability in the HRZ. · Kick tolerance is 92 bbls with a 12.3 ppg LOT. Hold a pre-drill meeting. Do not hesitate to shut in the well if flow is suspected after observing minor pit gains. Production Hole Section: · One fault is expected. Use LCM Decision Tree in the event of losses. · Faulting could cause drilling out of zone. Monitor drilling trends and cuttings. · Kick tolerance is Infinite. · Differential sticking had been experienced in other long horizontal sections. Keep pipe moving at all times. · Keep a minimum of 10.0 pgg EMW at all times. · S-12 fails Close approach in the production interval, but has been P&Ald. HYDROGEN SULFIDE - H2S · This drill-site not designated as an H2S drill site. Recent tests indicate a very low concentration of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE S-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 8-109 Permit to Drill ) 8-109 Proposed Completion Cellar Elevation = 35.9' Nabors ges KB = 28.5' 5-109 KBE = 64.4' j TAM Port Collar 11,000' I D 9-5/8", 40 #/ft, L-80, BTC 1 3,115' I 7",26 #/ft, L80, BTC-Mod I 71727' I 4-1/2" 12.6 #/ft, L-80, Solid I . j G ~ Q Q [QQ] .. - . M ') - TREE: FMC 4-1/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M csg.head wI 7" mandrel hanger & packott 11" x 11", 5M, tbg spool wI 11" x 4-1/2" tubing hanger 11" X 4-1/16" Adaptor Flange ~ 20" X 34" 215.5 I bItt, A53 ERW Insulated 109' D 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 2,200' TVD I ~ .,._.,.._.._,_.,_...._.._.._._----~_.- # 4 3 2 1 GAS LIFT MANDRELS Size Type 4-1/2"X1" KBG-2 4-1/2"X1" KBG-2 4-1/2"X1" KBG-2 4-1/2"X1" KBG-2 TVD 3800' 5000' 6500' 6600' Valve Type DCK Shear DV DV DV _w_..._·..____.·_.______,~_...,,_~~ -----_._-"_._---_.__._.,._-,_..~ 4-1/2", 12.6 Ibltt, L-80, TCII - Coupling 00: 4.932" Orift/IO : 3.833"/3.958" 4-1/2" 'Baker CMD Sliding sleeve with Landing Nipple with 3.813" 10 - 1 jt above packer 17,527' I 7-5/8" x 4-1/2" Baker '5-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go 10. 4-1/2" wireLin~ntry Guide spaced-out into 4-1/2" liner tie-back sleeve. 17,577' 1 BAKER 5" x 7" Liner Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger /" 4-1/2" 12.6 #/ft, L-80, Slotted Cemented Bonzai ECP I 9,227' I \ 1:)1 II"L.IJ:I I Date 12/12/02 Rev By Comments RBT Proposed Completion AURORA WELL: 5-109 API NO: BPX Aurora I 11 ,530' I ......,. -I ../ I . ') t- Z :'5 a. -~ ~- I S-PAD N 1100--!" j) . . . . .. .... N ~ .. .. .. I I I J, II) II) II) '-- ~ I- ã: c:> (\ z ¡::: ~ (f) x w ~ ::: I- o ..J (f) (f) ~......... ~~Ñ~~ª~2 ~~o ~ªª§ J,J,gJ,J,J,J,J, J,gJ, J,J,J, II) II) N 1 01 0 N 840 ~I l{) c.o 3: LEGEND + AS-BUILT CONDUCTOR . EXISTING CONDUCTOR NOTES: 1. DATE OF SURVEY: JUNE 15, 2002. 2. REFERENCE FIELD BOOK: W002-08 PG. 07. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD 27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.9999165. 6. HORIZONTAL CONTROL IS BASED ON MONUMENTS S-3 & S-4. (HELD S-4) 7. BASIS OF VERTICAL CONTROL IS OPERATOR MONUMENTA TION. ELEVA TIONS ARE BP EXPLORA TON MEAN SEAL LEVEL DATUM. ) 2 ¡' ')C' 'd) 26 --'-' --,._._"~_.._,- -,.-.---,-.--------..---- S PAD ~ t5 .34 .36 T, 12N. IU1N, -----,---- 2 VICINITY MAP N.T.S. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JUNE 15, 2002. LOCATED WITHIN PROTRACTED SEC. 35, T. 12 N., R. 12 E., UMIAT MERIDIAN, ALASKA SLOT A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINA TES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS SLOT 2 Y= 5,980,535.15 N. 1009.97 70'21'19.704" 70.3554733" 35.8' 4,332' FSL X= 618,929.92 E. 319.81 149"02'02.967" 149.0341575" 4,501' FEL y= 5,980,670.18 N. 1009.91 70"21'21.032" 70.3558422" 35.9' 4,466' FSL SLOT 11 x= 618,929.81 E. 184.76 149"02'02.908" 149.0341411" 4,498' FEL Y=5,980,730.34 N. 1010.61 70"21'21.624" 70.3560067" 35.6' 4,527' FSL SLOT 15 X= 618,930.49 E. 124.60 149"02'02.860" 149.0341278' 4,497' FEL FROb' DR A....'N , ,., COTTON ~M~b L~ 1- r CHE CKED' ALLISON ~..- -.... ..~ ~.. ~] .. DATE, ~;~,~~~ P ~ L_ --~ ¡ 6/16/02 ,'1ft' DRAWING: FRB02 WOA-S 07-00 WOA S-PAD SHEET "I (U~~[)r~O JOB NO' SCALE: AS-BUlL T CONDUCTOR WELL (NON(CAS 6HO lAND '5UAIo'(VORS ,"", '00' SLOT NO·S. 2. 11 AND 15 1 Of' 1 1101 W[".i' f"IACw((O lAk( ANOtOIU.cr.:. A.&.ASI<A H!lOJ --------- . 0 06/17/02 ISSUED FOR INFORMATION NO. DA TE REVISION JJC DAD BY CHK KBE KOP Cry 1.5/100 Cry 3/100 Base Gubik End Cry 8V6 Base Perm Cry 4/100 bp Report Date: Client: Field: Structure 1 Slot: Well: Borehole: UWI/API#: Survey Name 1 Date: Tort 1 AHD I DDII ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid N/E Y/x: Grid Convergence Angle: Grid Scale Factor: 8-1 09 Proposed Well Profile - Geodetic Report December 11, 2002 BP Exploration Alaska Prudhoe Bay Unit - WOA (Drill Pads) Sop AD / Plan S-109 S-1 09 S-109 50029 S-109 (P5) / December 11, 2002 130.588° /7311.28 ft / 6.208 /1.071 NAD27 Alaska State Planes, Zone 4, US Feel N 70.35584233, W 149.03414107 N 5980670.180 ftUS, E 618929.810 ftUS -+{). 90965438 ° 0.99991607 III Fea51 Illty MD I Incl I Azim I TVD I VSec I NI·S I (ft) (0) (0) (ft) (ft) (ft) 0.00 0.00 90.00 0.00 0.00 0.00 275.00 0.00 90.00 275.00 0.00 0.00 300.00 0.37 90.00 300.00 0.08 0.00 400.00 1.87 90.00 399.98 2.02 0.00 408.33 2.00 90.00 408.31 2.30 0.00 414.43 2.18 90.00 414.40 2.52 0.00 500.00 4.75 90.00 499.81 7.64 0.00 600.00 7.75 90.00 599.20 18.41 0.00 700.00 10.75 90.00 697.89 34.32 0.00 800.00 13.75 90.00 795.60 55.31 0.00 900.00 16.75 90.00 892.07 81.34 0.00 1000.00 19.75 90.00 987.03 112.32 0.00 1100.00 22.75 90.00 1080.22 148.18 0.00 1200.00 25.75 90.00 1171.38 188.82 0.00 1284.21 28.28 90.00 1246.40 226.66 0.00 1669.14 28.28 90.00 1585.40 407.10 0.00 2071.11 28.28 90.00 1939.40 595.53 0.00 2127.88 28.28 90.00 1989.40 622.14 0.00 Station ID 8-109 (P5) report. xis Page 1 of 3 tu Survey 1 DLS Computation Method: Vertical Section Azimuth: Y Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed 1 Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .> True North: Local Coordinates Referenced To: Schlumbøpuøp Minimum Curvature / Lubinski 81.700° N 0.000 ft, E 0.000 ft KB 64.4 ft relative to MSL 35.9 ft relative to MSL 25.843° 57523.254 nT 80.819° December 31,2002 BGGM 2002 True North +25.843° Well Head -_ J -- EI·W I (ft) 0.00 0.00 0.08 2.05 2.33 DLS (0/100ft) 0.00 0.00 1.50 1.50 1.50 Grid Coordinates Northing I Easting (ftUS) (ftUS) 5980670.18 618929.81 5980670.18 618929.81 5980670.18 618929.89 5980670.21 618931.86 5980670.22 618932.14 Geographic Coordinates Latitude I Longitude N 70.35584233 W 149.03414107 N 70.35584233 W 149.03414107 N 70.35584233 W 149.03414042 N 70.35584233 W 149.03412443 N 70.35584233 W 149.03412215 2.55 3.00 5980670.22 618932.36 N 70.35584233 W 149.03412037 7.72 3.00 5980670.30 618937.53 N 70.35584233 W 149.03407839 18.61 3.00 5980670.48 618948.42 N 70.35584233 W 149.03398996 34.68 3.00 5980670.73 618964.48 N 70.35584233 W 149.03385947 55.90 3.00 5980671.07 618985.70 N 70.35584233 W 149.03368716 ,-," 82.20 3.00 5980671.48 619011.99 N 70.35584233 W 149.03347360 113.51 3.00 5980671.98 619043.30 N 70.35584233 W 149.03321936 149.75 3.00 5980672.56 619079.53 N 70.35584233 W 149.03292509 190.82 3.00 5980673.21 619120.59 N 70.35584232 W 149.03259159 229.06 3.00 5980673.82 619158.82 N 70.35584232 W 149.03228108 411.41 0.00 5980676.71 619341.13 N 70.35584230 W 149.03080037 601.83 0.00 5980679.73 619531.51 N 70.35584226 W 149.02925414 628.73 0.00 5980680.16 619558.41 N 70.35584226 W 149.02903571 12/11/2002-1 :17 PM Grid Coordinates Geographic Coordinates Station 10 MO Incl Azim TVD VSec Nt-S Et-W OLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) End Cry 2151.20 28.29 91.97 2009.93 633.04 -0.19 639.77 4.00 5980680.15 619569.45 N 70.35584174 W 149.02894606 SV5 2344.78 28.29 91.97 2180.40 723.31 -3.34 731.45 0.00 5980678.45 619661.16 N 70.35583311 W 149.02820161 SV4 2570.77 28.29 91.97 2379.40 828.69 -7.02 838.48 0.00 5980676.47 619768.22 N 70.35582302 W 149.02733252 SV3 3001.16 28.29 91.97 2758.40 1029.37 -14.02 1042.32 0.00 5980672.71 619972.13 N 70.35580383 W 149.02567732 9-5/8" Csg Pt 3114.72 28.29 91.97 2858.40 1082.33 -15.87 1096.10 0.00 5980671.71 620025.93 N 70.35579875 W 149.02524062 SV2 3166.96 28.29 91.97 2904.40 1106.68 -16.72 1120.84 0.00 5980671.26 620050.68 N 70.35579642 W 149.02503973 SV1 3555.34 28.29 91.97 3246.40 1287.78 -23.04 1304.77 0.00 5980667.86 620234.67 N 70.35577908 W 149.02354621 UG4 3941.44 28.29 91.97 3586.40 1467.82 -29.33 1487.63 0.00 5980664.47 620417.59 N 70.35576180 W 149.02206138 UG4A 4003.90 28.29 91.97 3641.40 1496.94 -30.34 1517.21 0.00 5980663.93 620447.18 N 70.35575902 W 149.02182119 UG3A 4110.65 28.29 91.97 3735.40 1546.72 -32.08 1567.77 0.00 5980662.99 620497.76 N 70.35575424 W 149.02141064 UG3 4332.09 28.29 91.97 3930.40 1649.97 -35.68 1672.64 0.00 5980661.06 620602.66 N 70.35574434 W 149.02055909 '-' UG1 4953.26 28.29 91.97 4477.40 1939.62 -45.79 1966.83 0.00 5980655.62 620896.95 N 70.35571653 W 149.01817027 MA 5268.96 28.29 91.97 4755.40 2086.83 -50.93 2116.35 0.00 5980652.86 621046.52 N 70.35570238 W 149.01695617 Na 5505.17 28.29 91.97 4963.40 2196.97 -54.78 2228.22 0.00 5980650.78 621158.43 N 70.35569177 W 149.01604779 Oa 5634.63 28.29 91.97 5077.40 2257.34 -56.88 2289.53 0.00 5980649.66 621219.76 N 70.35568598 W 149.01554995 Obf Base 5966.22 28.29 91.97 5369.40 2411.96 -62.28 2446.57 0.00 5980646.75 621376.85 N 70.35567109 W 149.01427479 Cry 4/100 6752.20 28.29 91.97 6061.53 2778.45 -75.07 2818.81 0.00 5980639.87 621749.21 N 70.35563580 W 149.01125222 6800.00 30.19 92.30 6103.23 2801.41 -75.94 2842.14 4.00 5980639.37 621772.55 N 70.35563340 W 149.01106278 6900.00 34.18 92.88 6187.85 2853.70 -78.37 2895.34 4.00 5980637.79 621825.78 N 70.35562670 W 149.01063081 7000.00 38.17 93.36 6268.55 2911.55 -81.59 2954.27 4.00 5980635.50 621884.75 N 70.35561784 W 149.01015230 7100.00 42.16 93.75 6344.96 2974.66 -85.60 3018.63 4.00 5980632.52 621949.16 N 70.35560682 W 149.00962971 7200.00 46.15 94.09 6416.68 3042.72 -90.37 3088.12 4.00 5980628.85 622018.71 N 70.35559371 W 149.00906547 7300.00 50.15 94.39 6483.39 3115.42 -95.89 3162.39 4.00 5980624.51 622093.05 N 70.35557854 W 149.00846241 CM1 7357.60 52.45 94.55 6519.40 3159.26 -99.39 3207.20 4.00 5980621.72 622137.91 N 70.35556893 W 149.00809857 7400.00 54.14 94.66 6544.74 3192.39 -102.12 3241.08 4.00 5980619.53 622171.82 N 70.35556143 W 149.00782347 7500.00 58.14 94.90 6600.45 3273.26 -109.03 3323.82 4.00 5980613.94 622254.66 N 70.35554246 W 149.00715164 End Cry 7546.61 60.00 95.00 6624.40 3312.17 -112.48 3363.64 4.00 5980611.12 622294.52 N 70.35553298 W 149.00682832 .~. Top HRZ 7546.63 60.00 95.00 6624.41 3312.19 -112.48 3363.66 0.00 5980611.12 622294.54 N 70.35553298 W 149.00682816 Base HRZ 7726.59 60.00 95.00 6714.39 3463.86 -126.07 3518.92 0.00 5980600.00 622449.99 N 70.35549566 W 149.00556750 Target 7726.61 60.00 95.00 6714.40 3463.88 -126.07 3518.93 0.00 5980600.00 622450.00 N 70.35549566 W 149.00556742 Top Kuparuk 7726.63 60.00 95.00 6714.41 3463.90 -126.07 3518.95 0.00 5980600.00 622450.02 N 70.35549566 W 149.00556725 7" Csg Pt 7726.65 60.00 95.00 6714.42 3463.91 -126.07 3518.97 0.00 5980600.00 622450.04 N 70.35549566 W 149.00556709 Cry 12/100 7746.61 60.00 95.00 6724.40 3480.73 -127.58 3536.19 0.00 5980598.76 622467.28 N 70.35549151 W 149.00542727 7800.00 66.34 96.03 6748.49 3526.97 -132.17 3583.59 12.00 5980594.93 622514.74 N 70.35547891 W 149.00504240 LeU (Top A sand) 7815.30 68.16 96.31 6754.40 3540.64 -133.68 3597.62 12.00 5980593.64 622528.79 N 70.35547477 W 149.00492848 S-109 (P5) report. xis Page 2 of 3 12/11/2002-1 :17 PM ...' Grid Coordinates Geographic Coordinates Station ID MD Inel Azim TVD VSee N/-S E/-W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 7900.00 78.23 97.73 6778.86 3618.73 -143.61 3677.98 12.00 5980584.99 622609.29 N 70.35544753 W 149.00427600 8000.00 90.13 99.29 6788.98 3713.78 -158.33 3776.19 12.00 5980571.83 622707.71 N 70.35540719 W 149.00347860 End Cry 8010.46 91.38 99.45 6788.84 3723.74 -160.03 3786.51 12.00 5980570.29 622718.06 N 70.35540253 W 149.00339481 Cry 6/100 8473.55 91.38 99.45 6777.73 4164.65 -236.07 4243.17 0.00 5980501.52 623175.83 N 70.35519413 W 148.99968711 8500.00 91.25 97.87 6777.12 4189.94 -240.06 4269.32 6.00 5980497.94 623202.04 N 70.35518319 W 148.99947479 8600.00 90.75 91.89 6775.38 4287.25 -248.56 4368.89 6.00 5980491.03 623301.72 N 70.35515981 W 148.99866634 8700.00 90.25 85.91 6774.50 4386.41 -246.65 4468.82 6.00 5980494.52 623401.60 N 70.35516486 W 148.99785491 Target 8748.71 90.00 83.00 6774.40 4435.07 -241.94 4517.31 6.00 5980500.00 623450.00 N 70.35517765 W 148.99746116 8800.00 89.84 79.93 6774.47 4486.34 -234.33 4568.02 6.00 5980508.41 623500.58 N 70.35519836 W 148.99704936 8900.00 89.53 73.94 6775.03 4585.95 -211.73 4665.38 6.00 5980532.56 623597.56 N 70.35525994 W 148.99625870 9000.00 89.22 67.94 6776.13 4684.14 -179.09 4759.85 6.00 5980566.69 623691.49 N 70.35534894 W 148.99549145 c~ 9100.00 88.92 61.95 6777.76 4779.84 -136.77 4850.39 6.00 5980610.44 623781.34 N 70.35546440 W 148.99475605 End Cry 9105.89 88.90 61.60 6777.87 4785.38 -133.98 4855.58 6.00 5980613.31 623786.49 N 70.35547201 W 148.99471389 TKA4 9342.03 88.90 61.60 6782.40 5007.09 -21.67 5063.25 0.00 5980728.89 623992.33 N 70.35577845 W 148.99302700 TMLV 11009.38 88.90 61.60 6814.40 6572.57 771.30 6529.62 0.00 5981544.97 625445.80 N 70.35794167 W 148.98111434 TO /4-1/2" Lnr Pt 11530.42 88.90 61.60 6824.40 7061.77 1019.11 6987.85 0.00 5981800.00 625900.00 N 70.35861753 W 148.97739120 LeQal Description: Surface: 4466 FSL 4498 FEL S35 T12N R12E UM Target: 4339 FSL 980 FEL S35 T12N R12E UM Target: 4223 FSL 5261 FEL S36 T12N R12E UM TO /4-1/2" Lnr Pt/ BHL: 202 FSL 2789 FEL S25 T12N R12E UM NorthinQ (Y) rftUSl 5980670.18 5980600.00 5980500.00 5981800.00 EastinQ (X) rftUSl 618929.81 622450.00 623450.00 625900.00 ~., S-109 (P5) report.xls Page 3 of 3 12/11/2002-1 :17 PM P054970 DATE 11/18/02 CHECK NO. P054970 DATE INVOICE I CREDIT MEMO VENDOR DISCOUNT NET DESCRIPTION GROSS 11/18/02 INV# CKll1402K PERMIT TO DRILL FEE 3~\o~ RECEIVE) DEC 1 7 2002 ALaska au& Gas Gons. Comnlsslon ênchorage . - THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ PAY BP EXPLORATION, PRUDHOE BAY UNIT PO BOX196612 ANCHORAGf;, AK99519-6612 TO THE ORDER OF NOV 18, 2002 : ****'$100.00**** NOTVALlD AFTER 120 DAYS II· 0 5 ~ G ? 0 II· I: 0 ~ ~ 2 0 3 8 ., 5 I: 0 ~ 2 ? a ., b II· " ...[.::.: ~: ~.::.:.: ::::.::: :.: :{~~:::~;~:;'7:..;~:.:.~s.~;:~~.~ ~~.~.~~:.:~; ~ .~;>...." r····:··~,ß~:~·....'}·....··....·~·..·· ..... .... ·C&jJ.}j{~!~~~i~t~;¡;~;¡i~~:~~f '1 H ~ .- ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No,· API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY . ~¡:; ;X WELL NAME t~¿¡ .5.;/6 ¡PROGRAM: Exp _ Dev ~ Redrll _ Re-Enter _ Serv _ Wellbore seg _ FIELD&POOLC<¡d/t:~ INITCLASS /),0.:1/ ;-o/J GEOLAREA ~7~ UNIT# /1b.0A ON/OFFSHORE o,..J ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 0 N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . .. . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. W ell located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N t() ~ I, ) ._) 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N Af.£-- )~ð2-. 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . \j/ N (Service Well Only) 13. Well located w/in area & strata authorized by injection order #_ Ÿ)ý /1~,'¡::¡ ¥ (Service Well Only) 14. All wells wlin ~ mile area of review identified. . . . . . . . .. Y N ENGIN . . c\ N -S '-i If }i Z.ð'( €J loa EERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . IJ/ . 1 . 16. Surface casing protects all known USDWs. . . . . . . . . . @ N A . ..L 17. CMT vol adequate to circulate on conductor & surf csg. . . . (J) N . - du1)../t .A/L-1.··(!.-'t C-¡J c,ç . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y @ U 19. CMT will cover all known productive horizons. . . .. . . . . . . ¡~ 20. Casing designs adequate for C: T, B & permafrost. . . . . . . .. N ¡J~ L ~ r ~ q (; ç 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N ~ . 22. If a re-d rill , has a 10-403 fo~ abandonment been approved. . . .~ N fA- 23. Adequate wellbore separation proposed.. . . . . . .. . . . . (:f) Nt. t' J. .J 24. Ifdiverterrequired, does It meet regulations. .. . . . . . . . ~~,N ~t\:..-tVt'Ý' I{'-bhtf..LÇ ea, ~j) ~¡r.ud ¡o ~4Ç t,,~ ,$" (i\ ~''1Yf-e-LV<- ¡.v.{ll þ¿?.....(, 25, Drilling fluid program schematic & equip list adequate. . . . . {;¡¿I N ~~ mf¡..f TO ¡ ; P (J&;, . 5LcvvU ¡.,'f:.¡v¡/ t 12../ z·o . 26. BOPEs, do they meet regulation. . . . . " . . . . . . . . . . ð!.. N APPR DATE ~7: BOPE press rating appropriate; testto Lf"Oc> psig. 62 N Me.. r:::> 'Z~ 7~:.{ P ~¡ . WGA-L2..-f?..7Io L 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 8? N 29. Work will occur without operation shutdown. . . . . . . . . . . ~) 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y {DI" 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥--N" Ai/A G)N fi N. /1. APPR DATE (Service Well Only) GEOLOGY APPR DATE ,f!¿ ¡-z/ 1lþ2., (Exploratory Only) (1- 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact name/phone for weekly progress reports. ...... ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING ule ENGINEER COMMISSIONER: Commentsllnstructions: RP~/G TEM JDH JBR eOT . DTS ¡-zf,( 'i/O 1- ...,/ MJW MLB IYJ'l"'Þ¿ SFD WGA Rev: 10/15/02 - G:\geology\permits\checklist.doc ) ) Well ~-1istory File APPENDIX Information of detailed nature that is not particularly gemìane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomìation, information of this nature is accumulated at the end of the file under APPEN,DIX. No special effort has been made to chronologically organize this category of information. ) ) a~,-aLJ5 /1(¡;45 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 17 09:32:24 2003 Reel Header Service name........... ..LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 04/ 1 7 Origin. . . . . . . . . . . . . . . . . . .STS Reel Name............... . UNKNOWN Continuation Number.... ..01 Previous Reel Name. ..... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 04/ 1 7 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 3S-15 501032044400 Conoco Phillips Alaska, Inc. Sperry Sun 17-APR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 2 AK-MW30003 P. SMITH D. BURLEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 18 12N 8E 2524 1091 .00 56.65 27.70 # WELL CASING RECORD 1ST STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 3562.0 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: ) -) 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , UTILIZING GEIGER MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4); STABILIZED LITHO-DENSITY (SLD); COMPENSATED THERMAL NEUTRON POROSITY (CTN); ACOUSTIC CALIPER (ACAL); BI-MODAL ACOUSTIC TOOL (BAT); AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUNS 1-2 REPRESENT WELL 3S-15 WITH API # 50-103-20444-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8420' MD I 6209' TVD. SROP SGRC SEXP SESP SEMP SEDP SFXE SBD2 SC02 = SNP2 CTFA CTNA TNPS DTCP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED GAMMA RAY - GEIGER-MULLER TUBE DETECTORS SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING) SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) SMOOTHED FORMATION EXPOSURE TIME SMOOTHED BULK DENSITY (LOW-COUNT BIN) SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) SMOOTHED INTERVAL TRANSIT TIME OF COMPRESSIONAL WAVE, POST-WELL PROCESSED PARAMETERS USED IN NEUTRON I POROSITY LOG CALCULATIONS: HOLE SIZE: 8.5" MUD WEIGHT: 9.4 - 12.4 PPG MUD FILTRATE SALINITY: 100 - 800 PPM CHLORIDE FORMATION WATER SALINITY: 25000 PPM CHLORIDE FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE FORMATION WATER RESISTIVITY: 0.15 OHMM $ File Header Service name... .... ..... .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation. ..... .03/04/17 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE DTC PEF NCNT FCNT FET RPD RPM RPS RPX GR NPHI DRHO RHOB ROP $ ) ) and clipped curves; all bit runs merged. .5000 START DEPTH 3500.0 3500.5 3500.5 3500.5 3533.0 3533.0 3533.0 3533.0 3533.0 3540.5 3556.5 3561.0 3561.0 3572.5 STOP DEPTH 8306.5 8345.5 8329.5 8329.5 8381.0 8381.0 8381.0 8381.0 8381.0 8388.5 8333.0 8345.5 8345.5 8420.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ # REMARKS: BIT RUN NO MERGE TOP 2 3500.0 MERGE BASE 8420.0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ............. ..0 Data Specification Block Type.....O Logging Direction....... ..... .... . Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 DTC MWD USPF 4 1 68 56 15 ') ) First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3500 8420 5960 9841 3500 8420 ROP MWD FT/H 11.01 320.26 170.271 9696 3572.5 8420 GR MWD API 48.46 413.86 122.165 9697 3540.5 8388.5 RPX MWD OHMM 0.78 1798.13 3.99241 9697 3533 8381 RPS MWD OHMM 0.77 2000 4.28769 9697 3533 8381 RPM MWD OHMM 0.77 2000 8.31507 9697 3533 8381 RPD MWD OHMM 0.62 2000 13.6208 9697 3533 8381 FET MWD HOUR 0.1628 106.609 1.47254 9697 3533 8381 NPHI MWD PU-S 9.61 55.17 33.828 9554 3556.5 8333 FCNT MWD CNTS 596 2872.9 977.659 9659 3500.5 8329.5 NCNT MWD CNTS 115818 203810 139162 9659 3500.5 8329.5 RHOB MWD G/CM 1.994 3.135 2.32231 9570 3561 8345.5 DRHO MWD G/CM -0.126 0.345 0.0542269 9570 3561 8345.5 PEF MWD BARN 1.81 14.88 3.80366 9691 3500.5 8345.5 DTC MWD USPF 51 138 110.939 9614 3500 8306.5 First Reading For Entire File... ..... ..3500 Last Reading For Entire File......... ..8420 File Trailer Service name...... ...... .STSLIB.001 Service Sub Level Name... Version Number..... .... ..1.0.0 Date of Generation...... .03/04/17 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/17 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Cormnent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE DTC PEF NCNT FCNT FET RPD RPM 2 header data for each bit run in separate files. 2 .5000 START DEPTH 3500.0 3500.5 3500.5 3500.5 3533.0 3533.0 3533.0 STOP DEPTH 8306.5 8345.5 8329.5 8329.5 8381.0 8381.0 8381.0 ) ') RPS 3533.0 8381.0 RPX 3533.0 8381.0 GR 3540.5 8388.5 NPHI 3556.5 8333.0 DRHO 3561.0 8345.5 RHOB 3561.0 8345.5 ROP 3572.5 8420.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN BAT $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON Bi-modal Accostic # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type... ..0 Logging Direction.. ......... ..... . Down 17-JAN-03 Insite 66.37 Memory 8420.0 3540.0 8420.0 8.9 55.6 TOOL NUMBER 155789 134758 151842 174114 166359 8.500 3562.0 LSND 12.00 49.0 8.6 800 5.8 1.700 1.140 1.550 2.100 81.0 124.3 80.0 80.0 " ) ) Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing..................... 60 .1IN Max frames per record........ ... ..Undefined Absent value......... ............ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 DTC MWD020 USPF 4 1 68 56 15 Min 3500 11.01 48.46 0.78 0.77 0.77 0.62 0.1628 9.61 596 115818 1.994 -0.126 1.81 51 Name DEPT ROP MWD020 GR MWD020 RPX MWD020 RPS MWD020 RPM MWD020 RPD MWD020 FET MWD020 NPHI MWD020 FCNT MWD020 NCNT MWD020 RHOB MWD020 DRHO MWD020 PEF MWD020 DTC MWD020 Service Unit FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN USPF Max 8420 320.26 413.86 1798.13 2000 2000 2000 106.609 55.17 2872.9 203810 3.135 0.345 14.88 138 Mean 5960 170.271 122.165 3.99241 4.28769 8.31507 13.6208 1.47254 33.828 977.659 139162 2.32231 0.0542269 3.80366 110.939 First Reading For Entire File........ ..3500 Last Reading For Entire File........ ...8420 File Trailer Service name... ......... .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/04/17 Maximum Physical Record. .65535 File Type... ............ .LO Next File Name.......... .STSLIB.003 Physical EOF Tape Trailer Nsam 9841 9696 9697 9697 9697 9697 9697 9697 9554 9659 9659 9570 9570 9691 9614 First Reading 3500 3572.5 3540.5 3533 3533 3533 3533 3533 3556.5 3500.5 3500.5 3561 3561 3500.5 3500 Last Reading 8420 8420 8388.5 8381 8381 8381 8381 8381 8333 8329.5 8329.5 8345.5 8345.5 8345.5 8306.5 ) ') Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/04/1 7 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name......... ...... .UNKNOWN Continuation Number..... .01 Next Tape Name........ ...UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. ........ ... .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 0 3 / 04 / 1 7 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Next Reel Name....... ....UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
