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191-046
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 11, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC B-31 PRUDHOE BAY UNIT B-31 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/11/2025 B-31 50-029-22152-00-00 191-046-0 W SPT 8337 1910460 2084 1266 1266 1266 1264 2 4 2 10 4YRTST P Guy Cook 5/3/2025 Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT B-31 Inspection Date: Tubing OA Packer Depth 20 2341 2197 2168IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250503065920 BBL Pumped:1.4 BBL Returned:1.3 Wednesday, June 11, 2025 Page 1 of 1 9 9 9 99 9 9 999 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.06.11 15:39:42 -08'00' MEMORANDUM I State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg�`j DATE: Wednesday, May 19, 2021 P.I. Supervisor ' `-% 5'7l'Zot'l SUBJECT: Mechanical Integrity Tests !! Hilcorp Non], Slope, LLC B-31 FROM: Adam Earl PRUDHOE BAY UNIT B-31 Petroleum Inspector Src: Inspector Reviewed By: P.1. Supry 13 NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT B-31 API Well Number 50-029-22152-00-00 Inspector Name: Adam Earl Permit Number: 191-046-0 Inspection Date: 5/18/2021 Insp Num: mance210518194802 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min — Well B-31 E--- .Type In'J - —-__ W ITVD - 8337 Tubing 231 - 231 231 233 T PTD 1910460 -,TypeTest I SPVTest. psi _-i, 2084 IA 22 2351 - 2210 - 2186 BBL Pumped: 1.5 ' :BBLReturned: 1.5 - OA 9 10 - 9 8 Interval 4YRTST ;P/F P Notes: MIT IA Wednesday, May 19, 2021 Page I of I STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATI 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well ❑ Other: OA Cement Squeeze Ezi Convert WAG to WIND 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 191-046 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ® 6. API Number: 50-029-22152-00-00 7. Property Designation(Lease Number): ADL 028310 8. Well Name and Number: PBU B-31 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 9840 feet Plugs measured 9375 feet true vertical 9228 feet Junk measured 9294 feet VAY 2 2 2017 Effective Depth: measured 9375 feet Packer measured 8811 feet true vertical 8824 feet Packer true vertical 8341 feetAOG CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 32-112 32-112 Surface 2646 13-3/8" 31-2678 31-2678 5020 2260 Intermediate 9144 9-5/8" 29-9173 29-8650 6870 4760 Production Liner 933 7" 8905-9838 8422-9228 7240/8160 5410/7020 Perforation Depth: Measured depth: 9290-9490 feet True vertical depth: 8751-8924 feet Tubing(size,grade,measured and true vertical depth) 7"26#L-80 27-8912 27-8426 Packers and SSSV(type,measured and 7"Baker SABL-3 Packer 8811 8341 - true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): JUNTreatment descriptions including volumes used and final pressure: SCANNED 1 5 201:., 13. Representative Daily Average Production or Injection Data I Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1800 400 Subsequent to operation: 5406 720 450 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory ❑ Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ® WAG 0 GINJ ❑ SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-080 Authorized Name: Lastufka,Joseph N Contact Name: Montgomery,Travis J Authorized Title: Inf 'on and n Iler Contact Email: Travis.Montgomery@bp.com Authorized Signature: Date:512 3-i 11 Contact Phone: +1 907 564 4127 Form 10-404 Revised 04/2017 (o/7/ I R B D M S I t 1 I�v 2 1 4 2017 Submit Original Only /# 677/7' F • • RECEIVED MAY 222017 AOGCC Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary May 19, 2017 To Whom It May Concern: Attached please find the Report of Sundry Well Operations requesting conversion of PBU B-31 (PTD 1910460) to "Water injection, single completion" status from "Water alt gas injection" status. The requested change in status would help ensure that the well isn't tested to the higher pressures required for MI. The well was recently treated with two outer annulus down squeezes to repair a production casing leak in conjunction with a Seal-Tite treatment through the wellhead to mitigate IA by OA communication. The well passed an AOGCC witnessed MIT-IA on 05/09/17 to 2,388 psi proving two competent wellbore barriers. ✓ Sincerely, Travis Montgomery BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • . [ Daily Report of Well Operations B-31 ACTIVITYDATE SUMMARY T/I/O = 0+/230/240. Temp = SI. Assist HES (OA squeeze). Monitored wellbore pressures and stood by to bleed as needed while HES Cemented the OA. FWPs = 0+/1040Nac. 12/23/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 1810 hrs. Initial T/I/O= 2/228/245 Temp=S/I (LRS Unit 76 -Assist Cementers: OA CMT SQZ) Pre heated 50 bbls of diesel from 20*90* Spear in to OA with 5 bbls of 0* meth followed by 52 bbls of 150*diesel Halliburton in Control of Well Upon Departure. WV=closed, Swab, SSV, MV=Open. IA, OA = OTG. 12/23/2016 Final T/I/O=3/239/256 psi HES Cementing: Job Scope: OA Cement Downsqueeze: MIRU HES cement van and bulk trucks and LRS pump truck. Pump 5 bbls neat McOH spear, 50 bbls 160 deg diesel, 10 bbls 60/40 McOH, 100 bbls fresh water mixed w/2 gal/bbl MUSOL-A and 2 gal/bbl Surf- B, 10 bbls Clean Spacer, 10 bbls neat Class "G" cement, 50 bbls Class"G" cement w/ 15 lb/bbl Pressure Seal Aggregate, and 140 bbls neat Class"G" cement. Observe pressure bump of 600 psi after hesitating with aggregate at shoe. Shut down pumps and hesitate/squeeze again to a final pressure of 600 psi. Cement top estimated to be at 12/23/2016 surface. Rig down iron from OA, clean out and service OA casing valve. RDMO. ***Job T/I/O=SSV/400/0. Pre Cement Squeeze. Pull 2" FMC VR plug and N/U 2" integral blind and block valve on comp OA side, N/D 2" FMC OA valve and N/U 2" integral blind and 12/24/2016 block valve on working OA side. Did not PT. ***Job Complete***See log. Final WHP's T/I/O = SSV/70/VAC. Temp = SI. WHPs (post cement squeeze). OA casing valve has been replaced w/integral &2' block valve. 12/24/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 22:00 T/I/O = SSVNACNAC. Temp = SI. WHPs (post cement squeeze). OA casing valves replaced w/ integrals &2" block valves. IAP decreased 70 psi in 14 hours. 12/25/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 14:00 T/I/O = SSVNacNac. Temp = SI. Bleed OAP, Strap TOC (pre OA squeeze). Integrals & 2" BVs installed on OA spool. 0 % LELs through wellhouse. TOC @ 21' (1.2 bbls) @ the 9 o'clock position, @ the 3 o'clock postion TOC @ VR profile w/a few threads showing. Hung OA cemented to surface signs. FWHPs = SSVNac/0. 12/26/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 13:00 T/I/O = 0+NacNac. Temp = SI. LPE (Assist Cameron). TBG FL @ surface, IA FL near surface, OA cemented. Used AL gas from well 10 to increase OAP to 500 psi and IAP started tracking slowly. Bled OAP off to 0 psi then increased IAP to 1110 psi, OAP tracked slowly. Bled IAP to 150 and OAP to 10 psi. Monitor WHPs 30 min. TP unchanged, IAP decreased 10 psi and the OAP increased 5 psi. Final WHPs = 0+/140/15. 1/28/2017 SV, WV(LOTO), SSV= C. MV= 0. IA, OA= OTG. 15:15 T/I/0=0/0/0, Temp=SI. LPE-IC (post cement squeeze). Stung into IC test port(0 psi). DHD pressured OAP to 500 psi, shut-in increase to monitor. IAP increased slowly to 200 psi in 20 min, test void tracking the IAP, but not the OAP. DHD bled OAP to 28 psi. DHD increased IAP to 1110 psi, monitor OAP. OAP increased from 28 to 335 psi in 30 min. IC test void is tracking the IAP pound for pound, but does 1/28/2017 not seem to be in direct communication with the OA. 2/7/2017 Prep f/WellLock top fill and squeeze on OA T/I/O = SSV/0+/0. Temp = SI. Assist SP. (Wellock). Wellock treatment complete, Pressure OA to 1000 psi w/ N2 (as per WSL), maintain & monitor N2 pressure. Continued 2/7/2017 on WSR 2-8-17. • . Daily Report of Well Operations B-31 Halliburton Cementers-Job Scope: Fill OA and Squeeze w/WeIlLock. Tag TOC @ 21' (1.24 bbls) . Prep f/WeIlLock top fill. Fill OA w/68 gal of well lock-squeeze to 2500 psi 1 hr.Bumped up from 2200 psi twice. Lost 175 psi final 15 mins (2325 psi final pressure) Bleed Welllock back and install 2" integral valves. Apply 1000 psi N2. DHD start 24 hr monitor period. 2/7/2017 ***Job Complete*** Continued from WSR 2-7-17. T/I/0 = SSV/0+/976. Temp = SI. Assist SP. (Wellock). Wellock treatment complete, Pressure OA to 1000 psi w/ N2 (as per WSL), maintain & monitor N2 pressure. Job cancelled for weather. Bled the OAP to 800 psi before departure. FWPs= SSV/0/800. 2/8/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 1415 hrs. T/I/0 = SSV/165/605. Temp = SI. WHP's. (Post Wellock). Casing temp = 101*. Sample temp= 92*. Wellock sample is the consistency of cold honey. Heater in the wellhouse is working properly and the door left cracked open. 2/9/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 23:45 T/I/0 = SSV/35/0+. Temp = SI. Increase OAP (Post Wellock). Casing temp = 102*. Sample temp = 92*. Wellock sample is the consistency of warm honey. Increased the OA from 0+ psi to 960 psi w/ N2. Monitored the OAP fall off and bumped up as needed. The IAP increased 130 psi during the OA increase. Heater left in the wellhouse and the door left cracked open. FWPs = SSV/165/670. 2/9/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 1700 hrs. T/I/0 = SSV/175/175. Temp = SI. WHP's. (Post Wellock). Heater down, called non- mobile. WH &Wellock sample @ ambient temp. Non-mobile is replacing heater. 2/10/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 22:30 T/I/0 = SSV/180/200. Temp = SI. WHPs (post Wellock). Casing temp = 80°. Wellock sample has hardened and is set up solid, Wellock sample is warm to the touch and not frozen. Heater in wellhouse is working properly. IAP increased 5 psi and OAP increased 20 psi overnight. 2/11/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 14:00 hrs. T/I/0 = SSV/180/190. Temp = SI. WHPs (post Wellock). Casing temp = 80°. Wellock sample is hard. Heater in wellhouse is working properly. OAP decreased 10 psi since 2/11/17. 2/13/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 09:00. T/I/0 = SSB/180/170. Temp = SI. WHPs (Post Wellock). Casing temp —70* (heater removed 30 minutes prior). IAP remained unchanged and the OAP decreased 20 psi since 2-13-17, Heater released. 2/15/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 0850 hrs. T/I/0 = SSV/170/160. Temp = SI. WHPs (post Wellock). Casing temp = 50°. IAP decreased 10 psi., OAP decreased 10 psi. overnight. Heater installed inside the wellhouse, left door cracked. Wellock sample is hard. 2/16/2017 SV, WV, SSV= C, MV= O. IA and OA OTG. 16:00. T/I/0 = SSV/170/150. Temp = SI. WHPs (post Wellock). Casing temp= 28°. OAP decreased 10 psi., Casing temp decreased 22° overnight. Heater installed inside the wellhouse, left door cracked. Wellock sample is hard. 2/17/2017 SV, WV, SSV= C, MV= O. IA and OA OTG. 15:00. T/I/0 = SSV/160/150. Temp = SI. WHPs (post Wellock). Casing temp = 38°. IAP decreased 10 psi., Casing temp increased 10° overnight. Heater installed inside the wellhouse, left door cracked. Wellock sample is hard. 2/18/2017 SV, WV, SSV= C, MV= O. IA and OA OTG. 09:00. TWO =Vac/160/140. Temp = SI. TBG & IA FL (pre MIT). Casing Temp =40°. TBG FL @ 780' (29 bbls). IA FL near surface. Heater installed in WH, left door cracked open. 2/19/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 23:00 • e Daily Report of Well Operations B-31 T/I/O = SSV/170/150. Temp = SI. WHPs (post Wellock). Casing temp= 40°. IAP increased 10 psi and OAP unchanged. Casing temp decreased 22° overnight. Heater hose is installed inside the wellhouse, left door cracked. 2/19/2017 SV, WV, SSV= C, MV= 0. IA and OA OTG. 12:30 T/I/O =Vac/170/150. Temp = SI. MIT-IA FAILED (Post OA squeeze). T FL @ 60' (2 bbls). IA F near surface. Used AL gas from B-10 to increase TP from a Vac to 1010 psi. Used 1.2 bbl of diesel to pressure IAP from 170 psi to 2500 psi. During pumping OAP started pressuring up. Bleed OAP to 0 psi. Established LLR-IA @ 0.4 GPM @ 2500 psi with open bleed on OA. Pressure IAP back up and performed MIT-IA with open bleed on OA. IA lost 90 psi in first 15 min, 84 psi in second 15 min and 174 psi total. Bled all WHPs to 0 psi. Returned 1 bbl from the IA. Tags hung. Final WHPs = 0/0/0. 2/20/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 17:00 T/I/0=7/6/0+, Temp=SI. LPE-IC, (MIT-OA, CMIT-IA/OA). DHD performing MIT-OA, CMIT IAxOA. Stung into IC test void (0 psi), monitor test void during MIT-OA to 1200 psi. DHD pressured OAP to 1200 psi, IC test void tracked with OAP during MIT-OA. Test void tracked OAP & IAP to 1200 psi during combo MIT-IA/OA. Bled IAP & OAP to 0 psi, 2/23/2017 installed Hoke valves in test ports for seal tite treatment. TWO = 7/4/8. Temp = SI. MITOA FAILED, LLR-OA @ 0.18 gpm @ 1200 psi, CMIT IAxOA to 1200 psi PASSED (eval IAxOA). IA @ surface, OA FL wellock. Use diesel to pressure OA from 8 psi to 1200 psi, lost 900 psi in 1 min. Established LLR-OA @ 0.18 GPM @ 1200 psi for 30 min. Performed CMIT IAxOA to 1200 psi, lost 45/45 psi in 1st 15 min, 9/9 psi in 2nd 15 min and 54 psi total. Pumped 0.5 bbls of diesel total for all test. Bled OA to 0 psi and the IAP tracked, returned 0.5 bbls. Tags hung. Final WHPs= 0/0/0. 2/23/2017 T/I/O = SSV/15/15. Temp = SI. Assist Cameron w/ N2 (LPE). Block valves installed in place of OA CV's. IA FL near surface. OA FL @ surface. Bled OAP from 15 psi to 0+ psi in 1 min (1 1/2 gallons of diesel), held open bleed.. Bled IAP from 15 psi to 0 psi in <1 min (all gas). Pressured IAP w/ N2 from 0 psi to 400 psi in 50 psi increments. OA drip turned into a trickle of diesel and when the IAP reached 400 psi a steady stream of N2 came from the OA reducing the 02 from 20.9%down below 18%. Bled IAP, OAP, and IA void to 0 psi all returing N2. Final WHPs = SSV, 0, 0. 3/12/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 11:00 T/I/0 = SSV/15/15 TEMP = SI PPPOT-IC Leak Path eval comn (FAIL) PPPOT-IC: Assist DHD Bleed down 15 psi of diesel off OA and IA. Stung into test void, 0 plus psi. Bled void to 0 psi. Monitored for 10 min no change in pressure. R/U nitrogen line pressure up IA in 50 psi increments. Saw pressure in test void immediately, also communication of diesel out OA after the fist 50 psi. Saw nitrogen out OA after reaching 200 psi on IA and stopped pressure at 400 psi. (FAIL) primary and secondary are NOT 3/12/2017 holding. Bleed down IA and OA to 0 psi. R/D equipment. T/I/0=SSV/14/12, Temp=Sl. Assist Seal Tite with CSG hanger repair. DHD bled IAP & OAP to 0 psi, maintaining open bleed. RU to Hoke valves on CSG hanger test ports. Flush through viod with diesel to verify communication across void. Establish leak rate (700 ml/min @ 3500 psi). Pump 2.1 liters 3/18/2017 of Turf-low into test void. Pressured void in incraments to 2000 psi, hold pressure until the • Daily Report of Well Operations B-31 T/I/O = SSV/14/12. Temp = SI. Assist Sealtite (IC void repair). OA wellocked to surface. Bled the IA to 0 psi in 15 seconds (all gas). Bled the OAP to 0 psi in -20 seconds (all fluid, -1 cup). Established injectivity through the IC void with DSL @ 700 ml/min @ 3500 psi. Used 2.1 L of Tur Flo sealant in increments to pressure up the IC void to 2000 psi. Let treatment cure overnight. Heater left in the wellhouse. Door left cracked open. FWPs= SSV/0/0. 3/18/2017 SV, WV= C. SSV, MV= 0. IA, OA= OTG. 1840 hrs. T/I/0=SSV/5/2, Temp=Sl. Assist Seal Tite with CSG hanger repair. DHD bled IAP& OAP to 0 psi, maintaining bleed. RU pump to Hoke valve in test port(1600 psi), void lost approx 400 psi over night. Pressured in incraments, void with Tur flow, to 3500 psi. Bumped up pressure as needed to maintain 3500 psi. Lost 250 psi in 45 min. Mixed Tur-flow/Gly-flow, re-pressured void to 3/19/2017 3000 psi. Pressure holding. Rigged off well to let product cure overnight. Left heat on T/I/0 = SSV/5/4. Temp = SI. Assist Sealtite (IC seal repair). IC void pressure = 1600 psi. Bumped up the IC void several times w/turflo. IC void pressure continued to fall off slightly. Mixed up a 70/30 % Tur flo/Gly flo mixture and purged the IC void. Pressured up in increments to 3000 psi (no pressure fall off for 40 minutes). Let seal polymerize overnight. Heater left in wellhouse. Door left cracked open. FWPs = SSV/0/0. 3/19/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 1900 hrs. T/I/O=SSV/0/0, Temp=SI. Assist Seal Tite with CSG hanger repair. RU pump to IC test void Hoke valve. Test void decreased to 850 psi overnight. Pressured void with Tur-flow/Gly-flow mixture from 2000 psi to 3500 psi in incraments during the day, the test void pressure continued to decrease not showing stabilization. Flushed the Tur- flow/Gly-flow out of the test void. Mixed up flex plug (1 liter) and injected it into the test 3/20/2017 void. Rig off well to let cure overnight, left heat on wellhead. T/I/0 = SSVNacNac. Temp = SI. Assist Seal tite (IC seal repair). IA& OA went on a vac overnight. IC void on arrival = 850 psi (Wind picked up overnight, more airflow in wellhouse, wellhouse interior temp decreased -40° overnight). Re-Pressured the IC to 1300 psi w/tur flo/gly flo mixture. Flushed IC void with 4L of DSL. Pumped 350 ML of Flex-Plug into IC void and pressured up to 300 psi. Rig down and allow Flex-plug to cure overnight with heater installed in wellhouse. 3/20/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 17:00 T/I/O=SSV/0/0, Temp=SI. Assist Seal Tite with CSG hanger repair. IC test void remained at 0 psi over night. RU pump and pumped 300 ml of Gly-flow into the test void in increments to 3500 psi. Unable to stabilize test void pressure, slow loss of pressure above 2200 psi. Flushed test void with diesel, mixed Tur-flow/Gly-flow(70/30) and pumped into test void (3500 psi). Void appears to be showing some stabilization with 3/21/2017 minor pressure loss. RD pump to let cure overnight. T/I/0 = SSV/0/0. Temp= SI. Assist Seal tite ( IC seal repair). IC void remained @ 0 psi overnight. Pumped 300 ML of Gly-flo into IC void.. Unable to stabilize IC void pressure @ 3500 psi. Flushed IC void with DSL Pumped 500 ML of 70/30 Tur-flow/Gly-flow mixture into IC void. Monitor void pressure for 1 hour to verify stabilization. IC void showed some stability with minor pressure loss. Rig down pump to let cure. 3/21/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 19:00 S • Daily Report of Well Operations B-31 T/I/O = 4/0/0. Temp = SI. MIT-IA PASSED to 2352 psi ( post wellhead repair), Max Pressure = 2500 psi, Target Pressure = 2250 psi. IC void @ 3350 psi (lost 150 psi overnight). Tbg FL & IA FL near surface. OA cemented to surface. Increased Tbg from 4 psi to 1038 psi using ALP from B-10. Used used 0.83 bbls of DSL to pressure up IAP from 0 psi to 2500 psi. IA lost 122 psi in the 1st 15 mins &26 psi in the 2nd 15 mins for a total loss of 148 psi in 30 mins. During test OAP increased to 1 psi & IC void increased 110 psi. Bled IAP to 0 psi (1 bbl). Hung tags. Final WHPs = 1040/0/0. 3/22/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 13:40 ***WELL S/I ON ARRIVAL***(cement squeeze (oa/ia dwnsqz)) RIG UP SWCP SLICKLINE 4522 4/1/2017 ***CONTINUED ON 04-02-17 WSR*** ***CONTINUED FROM 04-01-17 WSR*** DRIFTED &TAGGED TOP OF BKR RBP W/5.93 GAUGE RING @ 8,841' MD PULLED 7" RBP FROM 8,796' SLM 4/2/2017 ***WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** T/I/O = 140/1050/Vac. Temp = 138°. AOGCC MIT-IA PASSED to 2388 psi (reg compliance). Max pressure = 2500 psi. Target pressure = 2275 psi. IA FL @ surface. Used 0.7 bbls of Diesel to reach a test pressure of 2490 psi. IAP decreased 84 psi in the 1st 15 min & 18 psi in the 2nd 15 min for a total loss of 102 psi in 30 min. Bled IAP from 2388 psi to 500 psi in 10 min (0.6 bbls). Tags hung. FWHPs= 130/500/Vac. 5/9/2017 SV= C. WV, SSV, MV= O. IA, OA= OTG. 11:00 T/I/O = 140/550/20. Temp = 140*. WHPs (Post MIT). On PWI. TP increased 10 psi, IAP increased 50 psi and the OAP increased to 0+ psi since 5-9-17. 5/11/2017 SV= C. WV, SSV, MV= O. IA, OA= OTG. 1300 hrs. 'TREE= 6"X 7"CNV FLS WELLHEAD= 13-5/8"FMC • S NOTES:H2S READINGS AVERAGE 125 ppm ACTUATOR= BAKER C B-31 WH ON MI. WELL REQUIRES A SSSV WHEN ON I. KB.H.EV= 67.72' ET_E1/= 39.8T ; E �JOA t)P= 4900' OA TREA IED w/ —I 0'21'1 1 I 21' CEMETi7ID((12123/16) Max Angle= 35°Q 8429' WELLLOCK 11 2102' _17"OTIS RPB NP,D=5.963"1 Datum MD= 9425' (02/07/17) I1 Datum TVD= 8800'SS 1 1 20'CONDUCTOR,D=7 —tj 110' I, 13-3/8'CSG,68#,NT-80,CY HE,D=12.415' -I 2682' t Minimum ID = 5.963 " @ 2102' 7" OTIS NIPPLE Zt cr. 8806' —9-5/8"x 7"BKR SABL PKR w/TBG ANCHOR SEAL NP,D=6.0" L._._8868' 1-17"0715 R NP,0=5.963" 7"TBG,26#,L80,U4S,.0383 bpf,D=6.276" H 8906' 8906' —I 7"DUMMY SEAL ASSY [TOP OF 7"LM H 8906' µ 8$97' H ELMD TT LOGGED 12/29/91 8906' —9-5/8"X 7"TM/HY DRAULIC HANGER w/TRACK SLV,D=? 9-5/8"CSG,47#,NT8OS,NCSS,D=8.681" —{ 9175' –A Ilk I —9294'SLM —{FISI-t 7"PR FUUG BODY,OAL 29"(10/15/15) PERFORATION SUMMARY 9309' —17'MARKER JOINT REF LOG: ATLAS-BHCA,05/09/91 ANGLE AT TOP FERE: 300 @ 9290 r/v/v/v/./lI 9375" -1 TOP OF CEMENT(06/09/95) Note:Refer to Rod uction DB for historical perf data 11111111/1111 SIZE SPF INTERVAL Opn/Sgz DATE 11/11111/1/14 3-3/8" 4 9290-9370 0 05/31/92 g•••••• 9405' —TOP OF SAND(06/2/95) 4" 4 9370-9384 C 06/09/95 4" 4 9398-9454 C 06/02/95 1 4" 4 9460-9490 C 06/02/95 7"CSG,26#,L-80,NSCC,.0383 bpf,D=6.276 9759' 4111141 9798' H PBTD 1111111444 � _._.._ D 11111114 .4 9# [7"TBG,2 ,L-80S,BUTT___ ,.0371 bpf, =6.184" �—F 9840' DATE REV BY CM/VENTS DATE REV BY COMMENTS F RUDHOE BAY UNT 06128/91 N18E ORIGINAL COMPLETION 04/03/17 DG/JMD FULLED RBP(04/02/17) WELL: B-31 10/02/15 GJB/JMD PULLED 7"INSERT(09/16/15) PERMIT No:'1910460 01/29/16 GTW/TLI4FISH(7"FLOG)(10/15/15) API No: 50-029-22152-00 11/02/16 JR/JMD SET RBP(10/25/16) SEG 31,T11N,R14E,2105'FNL&1609'FEL 12/28/16 JD/J1.413 OA CMTD(12/23/16) 02/27/17 JP/JMD OA TREATED w/WELLLOCK BP Exploration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg C DATE: Tuesday,May 16,2017 P.I.Supervisor �Cl I i`(7 SUBJECT: Mechanical Integrity Tests " BP EXPLORATION(ALASKA)INC. B-31 FROM: Jeff Jones PRUDHOE BAY UNIT B-31 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvir ' . NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT B-31 API Well Number 50-029-22152-00-00 Inspector Name: Jeff Jones Permit Number: 191-046-0 Inspection Date: 5/9/2017 Insp Num: mitJJ170509212539 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well B-31 " Type Inj W 'TVD 8337 " Tubing 140 143 - 126 ' 122 - PTD 1910460 Type Test SPT Test psi 2084 - IA 1050 2490. 2406 - 2388 BBL Pumped: 0.7 BBL Returned: OA 0 0 0 0 Interval 4YRTST P/F P ✓ Notes: 1 well inspected,no exceptions noted. — SCANNED JUL1 )r; Tuesday,May 16,2017 Page 1 of 1 • I Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, May 15, 2017 2:54 PM To: AK, GWO SUPT Well Integrity;AK, OPS GC3 Facility OTL;AK, OPS Well Pad AB;AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM;AK, OPS GC3 Field OTL; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists; Boman,Wade; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J;AKIMS App User; AK, GWO Well Integrity Well Information Subject: OPERABLE: Injector B-31 (PTD# 1910460) Passed AOGCC MIT-IA post OA downsqueeze All, Injector B-31 (PTD#1910460)was made under evaluation on 04/30/2017 to determine the success of an OA downsqueeze and wellhead repair. The well has been online 14 days and has shown no signs of annulus repressurization. Additionally the well passed a AOGCC witnessed MIT-IA on 05/09/17 to 2,388psi proving two competent wellbore barriers. The well is now classified as Operable. Work Completed: 1. Slickline: Set RBP-Complete 2. Fullbore: MIT-T—Pass 3. Fullbore: Cement OA&treat with Well Lock—Complete 4. Slickline: Pull RBP—Complete 5. DHD: MIT-IA- Pass 6. Ops: Place well on water injection-Complete 7. DHD: Perform state witnessed MIT-IA—Pass Please Reply with any questions, SCOPtw Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WD 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday,April 30, 2017 5:33 AM To: AK, GWO SUPT Well Integrity;AK, OPS GC3 Facility OTL;AK, OPS Well Pad AB;AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM;AK, OPS GC3 Field OTL; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists; Boman,Wade; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J;AKIMS App User Subject: UNDER EVALUATION: Injector B-31 (PTD# 1910460) POI to Evaluate Treatments All, WAG injector B-31 (PTD#1910460)was recently treated with two outer annulus down squeezes to repair a production casing leak in conjunction with a well lock treatment through the wellhead to mitigate IA by OA communication. The well has had a passing MIT-IA on 3/22/17 and a passing MIT-T on 10/25/16 proving two competent barriers. Once the injection rate is stable,a witnessed MIT-IA will be scheduled. The well has been reclassified as UNDER EVALUATION. Be mindful of fluid packed annuli. SCANNED MA Work Completed/Plan Forward: 1. Slickline:Set RBP-Complete 2. Fullbore: MIT-T—Pass 3. Fullbore:Cement OA&treat with Well Lock—Complete 4. Slickline: Pull RBP—Complete 5. DHD: MIT-IA-Pass 6. Ops: Place well on water injection 7. DHD: Perform state witnessed MIT-IA Please respond if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 �oF 74 • • � \ �������j ,s THE STATE Alaska Oil and Gas ,--,,yiw•-_,-..e....,-„iediThkli ALAsKA Conservation Commission 9�� ,kid:-4114- ,-' 333 West Seventh Avenue r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 = Main: 907.279.1433 (4S*1' Fax: 907.276.7542 www.aogcc.alaska.gov Aras Worthington Wells Engineer ,2 2 u 1 Z BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU B-31 Permit to Drill Number: 191-046 Sundry Number: 316-270, 316-368, 316-399 Dear Mr. Worthington: The AOGCC denies the enclosed applications for sundry approval relating to the above- referenced well. As provided in AS 31.05.080(a), 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal an AOGCC decision to Superior Court unless rehearing has been requested. Sincerely, Cathy . Foerster Chair DATED this?J day of August, 2016. RBDMS LA-- AUG - 4 2016 RE EIVED • STATE OF ALASKA `tom •ALASKA OIL AND GAS CONSERVATION COMM•N APPLICATION FOR SUNDRY APPROVALS MAY 1 j 2016 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 a io s shutdown 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 IA Cement Sqz 0 ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 191-046 ' 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic 0 Service RI. 6. API Number: 50-029-22152-00-00 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 RI PBU B-31 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028310 - PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9840 • 9228 • 9375 8824 9375 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"Conductor 32-112 32-112 Surface 2646 13-3/8"68#NT-80 31 -2678 31 -2678 5020 2260 Intermediate 9144 9-5/8"47#NT8OS 29-9173 29-8650 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 7"26#L-80 L-80 27-8912 Packers and SSSV Type: 7"Baker SABL-3 Packer Packers and SSSV MD(ft)and TVD(ft): 8811, 8340.72 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary H Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 13 - 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 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 Boman,Wade be deviated from without prior written approval. Email Wade.Boman@bp.com Printed Name Boman,Wade Title Production Engineer,B&X pads Signature !l-( Phone +1 9075644674 Date ,fes __�' U" �XCOMMISSION USE ONLY lJ� b Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Integrity \`-C �� O Plug g y 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No 11 Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: ORIGINAL _ RBDMS L AUG 4 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate MX///1.,6 /(/6. • ! a) Q, 0000 _0 (a comN — N N- O p N CO N- U N O O O O O L N I- V CO 3 O a0 N ,- N CO LO CO CO N- CO CO c- CO CO N N CO CO v- N N CO CA CA CO I I I A , H O N O N - C) CO N N CO CA a) N CO CO I� CO N N- 0) CO N- CO r- r aO O N 0) 0) C)) CO V CI Erni II 4.1 ++ r Q M LO N- N - O) O O) N- M CO M N 0) N- M a. O O) co O ° F CO O O CO oZI— aococo CD 73 I Z J J N C 00 *k *k *k *k CO N U N N N 00 V 000 N In v t ▪ O V N '— oo C CO CO V- CO a) (NI (3) CO -J CCW 0)O — CI- Wo U 0a CYCCZ Z Lt W W W O D H Z Z_ D U (n Z J • • • m CO co CO L O CO O p_ O N N V a (\I M 0) N D CO CO CO Cr) CO O CO CO H a 0 H V- V- N O t f- O CO CD a O O V O U O r coNco O > O 0 0 0 0 0 W 0 O• 0 w z CO H FW- O W 0 a a) Q Q J 0 w J J Y U 0 ct m 00 0 W Y Y H 0 co •::r V O J J J Q Q U) W4-1 �1� N M Oto mo- M V V 0 _0 < W w 0 0 - 0 W • O O O 0) 22 Z O00 -1 J J J E " « < a a a H II I 0 W < 01-- a 0 0 t w w w o I Q zpJ zQ C) 2 2 2 0 up co co co co COCO a Q 0 C D r 0 0 CO 0 MM a CA I- a) CO o W O N CO CO') 0. 0 0 0 0 0 L d ` 2 2 2 0 co co Q) W QD CL 0 U c .2 u.. N N to' a w O O � Qacncn a 0 t a> a. a, H o 0) (3) o ;7 :9 0 D D C O O O O w J J Z O \ \ W 6) Z 1 1 Q w 00 O W W O j LU N LU CO N N N Z d w J UW W w W U O CO CO co m o Y L Y w -1 -17z-' 0 w w < < C_ co LU a a a, E la z M (7 co co 00 d a a O J 00' NO w 0. 00mm00 Q Q m m w E cow o_ cC • • B-31 IA Cement Squeeze Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Wade Boman (907) 564-4647 History B-31 was swapped to PWI on 4-4-15. The well failed an MIT-IA on 6-26-15 and was SI. The IA was pressured to 1000 psi, the OA tracked, and a LLR of 0.3 BPM @1000psi/815psi IA/OA was recorded. A LPE (Leak Path Evaluation) was performed on the IC packoffs indicating that either the primary, secondary, or both IC packoffs were leaking. Note that this was done before the deeper IA x OA leak was discovered and thus in retrospect it was impossible to determine if both seals were leaking or the test was a false negative for one of the seals. A press/temp/acoustic LDL was performed on 12-28-15. Diesel was pumped down the IA, with returns up the OA, with a differential of 850 psi (IA 980, OA 130), at 3 bbl/min leak/pump rate. The deeper IA x OA leak was confirmed @ 2642' MD. An OA cement job was planned and sundry approval was received for this work. However, sufficient injectivity into the OA shoe could not be established. The revised plan is to perform an IA cement job to seal off the PC leak. Current Status The well is currently classified as "Non Operable" by BP due to the IA x OA leak. The well is therefore currently shut-in until the leak is fixed. Objective The objective of this job is to cement the IA and thus repair the IA x OA leak to make this well - operable. Cement will be pumped down the production tubing and circulated up the IA to above the PC leak. The goal is to have cement in the IA from the production packer to -500' MD. Procedural steps E-Line 1. Set bridge plug above production packer. 2. Punch tubing directly above the bridge plug. 3. Set cement retainer above tubing perforations. Fullbore 4. Circulate Class G cement down the production tubing and up the IA to get the TOC in the IA up to -500' MD. Fullbore 5. MITIA to 2500 psi. • Coiled Tubing • 6. Mill out cement retainer, residual cement, and bridge plug. DHD (contingent steps - if MITIA fails) 7. Perform Leak Path Evaluation on IC Packoffs if MITIA fails. 8. Perform sealant treatment on IC packoffs if both primary and secondary packoffs are found to be leaking. 9. MITIA to verify packoffs are sealed/repaired. DHD 10. Perform State witnessed MITIA to 2500 psi after injection has stabilized. &G -"_ c D:n 2 TREE= 6"X 7-aw R_S 1A FLU-EA 13- SAFETY NOTES:H2S READINGS AVAGE 126 ppm 5/8"FAAC ACTUATOR BAKER C B-3 1 w OPI MI. WELL REQUIRES A SSSV WHEN ON Ml. KB.EELEV= 67/7 OF.ELEV= 39,87' KOP= 4900' Mix Angle= 35°@ 8429 2107 _17-OTIS RPB NP, 5.963" Datum NO= 9425' EiUmTVD 8800'SS ?Akiky 20"CONDUCTOR,ID=? --I 110' t 'gfk.fr 13-3/8"CSG,68S,NT-80,CYHE,D=12.415" 268T — /I 1 Minimum ID = 3.813 " @ 2102' 4-1/2" SSSV NIPPLE im4 8806' —9-5iT x 7-BKR SABL PKR w rfBG ANO-&R SEAL NP, 8858' r OTtS R NP, =5.963' r TBG,26a,L80,U4S,.0383 bpf,ID=6276' H 8906' 8906' —IT DUMMY SEAL ASSY TOP OF 7"LNR I—E9906' • r Haw TI LOGGED 12129/91 8906' —9-5/8-x r TNN (YDRA UUC HANGER w/TIEBACK SLV,0=? 9-5/8"CSG,474,NTBOS.NCSS, =8.68r 1— 9175' I 9309' HT MARKER JOFIT 1 PERFORATION SUMMARY REF LOG: ATLAS-E3HCA,05/09/91 —1TOP OF cas.ENT(06409/95) ANGLE AT TOP FERE 30°ft.,9290 vrel .••••••1 Nola:Refer to Production DB for Vistorical pert data IS, '14 44 SIZE SF INTERVAL Opn/Sqz DATE 1.40 3-3/8- 4 • 9290-9370 0 05/31/92 9405' HTOP OF SAM)(06/2/95) 4- 4 9370-9384 C 06/09/95 4" 4 9398-9454 C 06/02/95 4' 4 9460-9490 C 06/02105 7-CSG,264,L-80,NSCC,.0383 bpf,0=6.276 MIZZEI 9798' —MID I 7-TBG,294,L-80S,BUTT,.0371 bpf,13=6.184- 1—f 9840' j 'AAA'AV LATE REV BY COMENTS DATE RBI BY COMMENTS F0-1)E BAY UMT 06/28/91 1118E ORIGINAL COMPLETION 10/02/15 GJB/JMD FULLED 7-INSERT(09/16/15) WELL_ B-31 02/15/11 /JM) ADDED SSSV SAFETY NOTE PERIAT No: 1910460 01/17/12 BIAN/Jkot)ADDED AftS SAFETY NOTE ARM): 50-029-22152-00 03/19/12 SET/AD RIO PLUG(03/14/12) SEC 31,T11N,R14E,2105'FAIL&1609'FEL 04/05/12 TFCLIMD I le±CD(04/04/12) 04/11/12 (1W/JM)R I I FRO PLUG(04/08/12) BP Exploration(Alaska) 3 STATE OF ALASKA SLASKA OIL AND GAS CONSERVATION COMMI APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 • Operations shutdown❑ 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 IA Cement Squeeze 0 • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 191-046 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612Stratigraphic 0 Service 0 6. API Number: 50-029-22152-00-00 • 7. If perforating: 8. Well Name and Numb e What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU B-31 • FIECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: J U L 15 20% ADL 028310 . PRUDHOE BAY,PRUDHOE OIL• 11. PRESENT WELL CONDITION SUMMARY AOGCG Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 9840 • 9228 • 9375 8824 9375 9294 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"Conductor 32-112 32-112 Surface 2646 13-3/8" 31 -2678 31-2678 5020 2260 Intermediate 9144 9-5/8" 29-9173 29-8650 6870 4760 Production Liner 933 7" 8905-9838 8421 -9226 7240/8160 5410/7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9290-9375 8751-8824 7"26#L-80 L-80 27-8912 Packers and SSSV Type: 7'Baker SABL-3 Packer Packers and SSSV MD(ft)and TVD(ft): 8811/8341 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary l• Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program fie- BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for Commencing Operations: 7/17/16 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ 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 Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name/�Worthingtonn,,Aras// JTitle Wells Engineer )) Signature rs�/ Phone +1 907 564 4102 Date /��b COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes❑ No 0/ Spacing Exception Required? Yes 0 No Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: ,de 7((ra ORIGINAL Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate .7-s.c1 7 te-// • • Well: B-31 B-31 IA Cement Squeeze Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Wade Boman (907) 564-4647 History B-31 was swapped to PWI on 4-4-15. The well failed an MIT-IA on 6-26-15 and was SI. The IA was pressured to 1000 psi, the OA tracked, and a LLR of 0.3 BPM @1000psi/815psi IA/OA was recorded. A LPE (Leak Path Evaluation) was performed on the IC packoffs indicating that either the primary, secondary, or both IC packoffs were leaking. Note that this was done before the deeper IA x OA leak was discovered and thus in retrospect it was impossible to determine if both seals were leaking or the test was a false negative for one of the seals. A press/temp/acoustic LDL was performed on 12-28-15. Diesel was pumped down the IA, with returns up the OA, with a differential of 850 psi (IA 980, OA 130), at 3 bbl/min leak/pump rate. The deeper IA x OA leak was confirmed @ 2642' MD. An OA cement job was planned and sundry approval was received for this work. However, sufficient injectivity into the OA shoe could not be established. The revised plan is toP erform an IA cement job to seal off the PC leak. Current Status The well is currently classified as "Non Operable" by BP due to the IA x OA leak. The well is currently shut-in until the leak is fixed. Reserves/Economics Over the next 10 years, there are 260,000 bbls of oil estimated to be recovered as a result of getting this well back on injection. Current economics do not support a full blown rig-workover, therefore this alternative integrity repair is proposed to regain operability of the well. Estimated IOR delivery for the well 150 BOPD. Objective The objective of this job is to cement the IA to seal-off the IA x OA leak and regain operability of the well. Cement will be pumped down the production tubing and circulated up the IA to above the PC leak. The intent is to have cement in the IA from the production packer to -500' MD. Post-Job Evaluation This well is an injector so an AA will be applied for with the following proposed evaluation criteria: ➢ MITIA and MITT ➢ SCMT to confirm Top of Cement (TOC) ➢ Temperature Warmback Log & Water Flow Log to verify no flow behind pipe • S • Long-Term Integrity Monitoring ➢ Daily pressure-monitoring of the 500' deep Inner annulus ➢ 2-year (biennial) MITTs and MITIAs Contacts: Aras Worthington Wade Boman 564-4102 (w) 907-564-4674 (w) 440-7692 (c) 206-687-4468 (c) 2 • TREE= 6-xr caw FLS • S • 1NH LfEA[> 13 515'1111CSAFETY NOTES IRS REALMS AYElA6E 125 ppm 101 a T01� B EV= 6717 - Current � ��AC ON NL NEJL REQO/t£SA SSSV H'P W BF_E.EV= 3927' il KP= 4900' ' ,Max Ample_ 35'fa 8429 2102' ___17"OAS RFD PI D=5.963' DW`NO= 9429 Dim 1V1: MOW SS 212'cO ucukD=? 110' 1339r CSG,688.11P110.GYM.D=1Z415' [-i 21182' Nir•ua a w= 313 (§2102' 4 ifrw SSSV NIPPLE f+1 0 8806' –9-SN'xr Bat SAW WR ra1IBG ANCHOR SEAL IN,D=6A' [ Mir [–7"0118 R 1411:171=5.963' T 786.M Lao,.MS,0383 bps.D=6,2776' - 9905' 8906' (-7'D NN SEAL ASSY 1OP OF 7'L'R H 8 8097' -{MID 7T LOGGED 12/2961 ' IH9—"'x r 7 W NYDRAIRE MANGER INF'WRACK SLV,D=? • 9-598'GSC,47911 NIaa MOSS.D=91..6x1' - 9175' -• ' 411* I -9294'51111 -F61t 7'Lit rum BODY_OAL 29'110H5f15) PEiFORATDN SUMMARY -7'MAKER JOINT RE=LOG=ATLAS-MICA,0599131 AIME ATTUP PERF_ 30'Q 9290 r*i'f 'tVi 9373'" H 70P OF CBENT[019091967 NaiecMario Pto�dwOBfor i9 0ad ipaddei��'� iHTf 1 iffct SPT= SPF INTERVAL OpoiS1g DATE kff t14f�. i 3-Nr 4 9290-9310 0 05/3092 WAWA*,, 9485" Imp OF SAM f 0621967 4' 4 9370-9354 C 06109195 4 4 9395-9454 C 0692195 4' 4 9460-9490 C 0692195 J 7-GSG.26115 L_ao.NScc.m83 bpf_D=6276 - 9759' .f'f'f'f".'Yf 9 -I [ ;f1•44.44014 .04:04i 04.41 7'11)G.,2911,us0S,,Burr__0371 bps.D=&184' 0' :.fid►.* .. DATE REV BY COMMENTS DATE REV BY COMMENT'S PR 13110E BAY MIN 81191171 NNE ONENIAL C11'LE1'ION 1010215 GJBlAO PILLED 7'WE RT(09116115) WE.L B31 0211511 MBFAO ADDS]SSSV SAFETY NOTE 01129/16 GPAUTLII FISH{7'RAG)ti anvils) PERIN-Naz 1910460 O1/17/12 TON/A113 ADD®IRS SAFETY NOTE AR Hoc 50429-2215203 O3119112 SE17AO PRO PLUG(03114112) SEC 31,T11N,R14E,210.9 FML A 1609 FE_ 04J0511 2 TPCFAO Tuff CJD[04/04/12) 04111112 DLWZ )RNL FRO RUG(04!05112) II'Ezplorauoo( 3 Ala= 6'x r CN1r RS • 2 MS REABNIGS AVERAGE 125 ppm WEILHEA ,BAKE B-31 Pest IA Cement AcnuaTof� BAKERWELL REQUINEsA SSW WREN ON 01 REV= 67.77 — BF-REV= — P= 4900" ' � fq ') sow _Tax N 14 Bax As*= 35"It 8429' �i 10= 9425'f „ DiINN1VD= WON SS Or coraucinst.o=7 110' 13.310'CSG.MK FI1OQ GYM.13=12415" [--I 2687 F iiMIENIMIN Q= 3.513"#12102' 112" SSSV NIPPLE sim. 0'04 _ MOW -i3-5B z?BKR SABLI1 IWHIG ANCHOR SEAL HP 17=6A' 8658 —7'0115 R Pat ID=5963' 7'1W3 LOO.U4S__0363 bpi.I)=6276' 8906' I 8906' -17'UMW SEAL ASSY 1 110P OF 7"UFR I 6906' rw, I 8897' 1H E_Ni]TT LO lame' 8906' I-19.518'xrTwIIYDRAIREHANGER t1ar7ACK SLY,D=2 9-5i9'CSG.47#MOOS_NcSS.o=&M1' — 9175' I -9294'SUN —Fist 7'IR ROB BODY.GAL 29'(1014515) PIBFORATION SlNN�ARY 9309' -di"MARKER JO.IT I REF LOG ATLAS-IIHGA 05169191 ANGLE E ATTDP PERE 30' 9290 Py��'4w�'j"' 9373' H NOP OF CR19(I(061 61) Nall Belem-10 I odwio�DB for ural pert deb :+:+tr 110. SIZE SPF INTERVAL Op&Sqz DATE WAWA 3-318" 4 9290-9370 0 0931192 :r_AMM r_i 9405' --kw,OF SAND(0612196) 4' 4 9370-9384 C 06109/35 4' 4 9396-9454 C 06102195 4' 4 9460-9490 C 06102195 11 I 7'CSO,2661.use.FdScx._x363 bp&to=6276 9759' r r•r � 9798' —lam, 40414444 BG, J teirr r*t+r`r 1 7'T290E LOOS.BUTT_A37/6p&u=6.104' H a' 44ar 44 DATE REV BY COIN83ITS DATE REV BY ROMWEfTS PRUDHOEBAYNIE- 06120191 NNE OR1681AL COOMPLE11011 10102/15 GAMIC RULED r 11SEiT(09/1615) TI R 1- 031 02/1911 AHD ADDED SSSV SAFETY NOTE 0112916 GTiI19'RH FM(r PLUG)(10115115) maw Nx x1910460 01117112 TINYH[I ADDED 1125 SAFETY NOTE MIND: 50-029-22152-00 03119/12 SE17H ) MN PLUG(03114/12) SEC 31,11111,R14E,21091111.91609'FEL 04105112 MONO TREE C )(04/04112) 04111/12 OLW1.M)RILL PRD PLUG(04/0012) IW Espiamtion 4 • Job Notes • • • IA x OA leak @ 2642' MD. 2-3 bpm @ 800-1000 psi. • PPPOT-IC failed. LPE test inconclusive (due to PC leak below) but indications are that one of the seals has integrity because the surface pressures on IA and OA do not track during pumping operations (see pumping WSR of 12/31/15) . Cement Calculations IA Cement(packer to 500' MD) 212 Bbls Total cement to pump 212 Bbls Key Parameters Ppg: 15.8 ppg Class G — Mix on the fly Slurry Temperature: between 80° and 110°F API fluid loss: 40 - 200 cc Thickening Time: Minimum 5 hours Compressive Strength: 2000 psi in 24—48 hours Cement thickening time: Mix on the fly Activity Time(hours) Shearing time,quality control,PJSM 0 Cement displacement 3 Cement contamination 0 Safety 2 Minimum required thickening time: 5 Cement Ramp for Blend Time I Temp Pressure 0:00 90 0 1:00 140 2800 2:00 140 2000 5:00 140 200 10:00 46 200 16:30 42 200 24:00 39 200 Volumes: top volume MD bot MD Size ID bbls/ft. Ft. bbls 9-5/8"47#x 8.681" 9-5/8" x 7" annulus 0 8800' 7"26# X 7" 0.0256 8800' 225 7" tubing 0 8800' 7"26# 6.276 0.0383 8800' 337 5 Eline/Eutfbore AO- 1. Set 7" composite bridge plug @ -8780' MD (middle of first full joint of tubing above production packer). 2. MITT to 3000 psi to verify the CBP will hold the pressure needed for the cement job. 3. Punch tubing w/ 5' tubing puncher from -8758' - 8763' (across the top collar of the first full joint of tubing. Note indication of TxIA communication in AWGRS. 4. Set 7" Magnum "Interventionless-CCR" cement retainer (sourced through Baker) @ -8739' MD (middle of second full joint of tubing above production packer). Note: All depths reference attached tubing tally dated 06/28/91. 6 Fulibore 410 1. RU wiper plug dropping assembly on the tree with pump rigged up to pump in below it, taking returns from the IA to tanks. Also, rig up in a way that returns can be diverted upstream of the tree (to make sure the water spacer ahead of cement can be diverted to tanks and not pumped down the well). 2. Pump the following schedule of fluids down the tubing with returns from the IA @ max rate achievable staying within a maximum pressure of 3000 psi: ➢ 560 bbls of 160E heated diesel ➢ FW spacer as needed (divert ALL of the FW spacer upstream of the tree so that the interface is diesel/cement. If the FW spacer were to be pumped into the well it would end up @ 500' MD in the IA and eventually freeze and collapse tubing). ➢ 212 bbls of Class G cement ➢ Drop wiper plug ➢ 337 bbls of 140F pre-heated 9.8 ppg brine (pre-heat the brine so that it can be pumped at a high rate; 2-5 bpm is preferred to get cement in place before it sets). ➢ Slow pump rate to minimum as the last few barrels are pumped and bump the wiper plug to 100 psi over circulating pressure. Note that the hydrostatic pressure difference between the cement in the IA and brine in the tubing will be —2350 psi so expect to need —3000 psi towards the end of the job. 3. If the plug was bumped, bleed pressure off of the tubing to 0 psi but bleed no more than an 5-bbls back to achieve this. If more than 5 barrels are returned before pressure is zero then assume that the retainer or wiper plug are not holding pressure and leave the remaining pressure on the tubing to keep cement in place. RDMO. 4. If the plug was not bumped, then leave —2500 psi on the tubing to keep cement in place and RDMO. Note: The 9.8 ppg brine will suffice as freeze-protection in the permafrost. The crystallization temperature of the brine is —0 deg F. If the job is pumped during winter months, however, a couple barrels of diesel will need to be substituted for the brine as the last few barrels are pumped to freeze protect the tree against ambient surface temperatures. 1. MITIA to 2500 psi. 1. RU with 7" BOP stack or plan to pick up the 7" milling BHA hanging below the 4-1/16" BOP stack. 2. Mill out retainers, cement, and CBP with 5.90" Mill or Mill + Underreamer. Push remnants past the open perfs to TOC @ 9375' MD. 7 • • St kht'EelEtit wore 1. Set Tubing Tail Plug in R-nipple @ 8858' MD. 2. MITT to 2500 psi. 3. Memory SCMT to locate bottom and top of cement in IA. 4. Pull TTP. f-� 1. WFL and temperature warmback log to indicate any flow behind pipe. oyf/ i.,%T/;,,J,�� ,r'�rr /��/i��/C�s�r'%�''�6�il�� �L/�X�� � � '14,1/4 1. After Injection has stabilized, perform AOGCC witnessed MITIA to 2500 psi. , Oda�33�aa 4 � 1. Add Biennial MITTs and MITIAs to AnnComm for additional monitoring of the well integrity. 8 • • 6-3 I TUBING SUMMARY 6- 2e-91 (a pprvo 7" IJ4S L-80 USED TBG. 26 LBS./FT. WELL No. B-31 NABORS 18E KB: 25.6' ATS 240 JTS. ON RACK 228 JTS. RAN 12 JTS. OUT 9296 FT. ON RACK 470.6 FT. OUT LAST CSQ: rides°, tinc LINER ITEM LENGTH TOP BOTTOM 7" DUMMY SEAL ASSEMBLY 6.53 8,899.68 8.90841 JT 1 1 JOINT 7" IJ4S 39,58 8,860.10 8,899.68 7" OTIS 'ANIPPLE 1.74 6,858.36 8,860.10 JT 2 1 JOINT 7" IJ4S 37.23 8,821 ,13 8,858.36 X/0 r TC4S X 7" NSCC 3.90 8,817.23 8,821,13 MILLOUT EXTENTION 6.64 8,810.59 8,817.23 9-5/8 'SABL' PKR WITBG ANCHOR 5.00 , 8,805.59 8,810.59 X/0 PUP r NSCC X 7" TC4S 6.23 8,799.36 8,805.59 JTS 3-175 7", L-80, IJ4S TBG 6,671 12 2,128.24 8,799.36 PUP JOINT TC4S 11 .17 2,117.07 2,128 24 SSSV LANDING NIPPLE/FLOW COUPL 14.89 2,102.18 2,117 07 PUP JOINT TC4S 12.75 2,089.43 2,102.18 JTS 178-229 7", L-80, IJ4S TBG 2,048.75 40.68 2,089.43 (LEAVE OUT JOINT NOS. 184 + 214) 1st. SPACE OUT PUP JOINT 'A' 10.60 -p,f, 14 30.08 40.68 X/0 7" TC4S X 7" NSCC 2.80 27.28 30.08 r RAC TUBING HANGER, CCL 1.68 25.60 27.28 RT - TS 25.60 0.00 25.60 Add Add. . ;WAN - 1141.1ti, 564CE couT PQ Iv , 5; to -- - o / -Th F. oF ..... it it • A 5petc4 RP Sol/Jr n I 9 P1C OCI V CV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION Co ION JUL 28 2016 APPLICATION FOR SUNDRY APPR LS 20 MC 25.280 AO ^ 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well RI Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program Q Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other IA Cement Sqz Cil 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 191-046 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic ❑ Service Ed 6. API Number: 50-029-22152-00-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No II PBU B-31 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028310 PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9840 9228 9375 8824 9375 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"Conductor 32-112 32-112 Surface 2646 13-3/8"68#NT-80 31-2678 31-2678 5020 2260 Intermediate 9144 9-5/8"47#NT8OS 29-9173 29-8650 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 7"26#L-80 L-80 27-8912 Packers and SSSV Type: 7"Baker SABL-3 Packer Packers and SSSV MD(ft)and TVD(ft): 8811, 8340.72 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program m BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service El 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG H GSTOR 0 SPLUG ❑ 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 Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Wells Engineer s Signature , .r X. ' Phone +1 907 564 4102 Date COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3\Lo -30i q Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No 0 Subsequent Form Required: ApprovedAPPROVED BYTHE by: COMMISSIONER COMMISSION Date: ORIGINAL Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • w p, 00000 cflcor- N N d O U i N VO CO Nt O CO N r N m to CO CO t` C+O O r CO (0 I,- LC) Cr) N N Cfl co r N d' N CO O) 0) CO a i H r r N r CA N O N- CO CO N r N CO CA C a CO CO CO N I� I,- Cp COr CO r f� CO CA N O) 0) 0) CO 4.11 i i I i I i QM N r CD CD rn I� O) CO C) N � N- • M• 0- O � O co co 000 C) oZZOococo N 040 *k J J J • ) 1 O O cn U N N N 0 OMOo cr Inti N r O L CD = CO CO r O CO J N O C° CO W F— Q C O — W 0 • U w co D U 0 U_ CKCCOLZ Z wwwm OJH _zz_ D O c Z J J • • ar u, (o co voocoao or- co0 Q O N N N CO C) N O coOcaa) co co c0 co F 0. 0 ~ 4 N CO . N- O CO O o- OO400 N LO N d' 6) W N- CO CO 00CI CO CO CO CO 0 > w � p CI p W z 1w- H a g Y U o > La U U < Y Y0 UU U LU LU 0) rn 03 rn m = _ = O= p° 0 o ~ 0_ . z W W 0 a z H z C.) 2 2 2 0 Cl) cn a) JO Q ci) 4.11 < o 0 C D y00000 MM 0) l` rn CO 0 W N M 0� A O O O 0) a) 0 LY U) 0 0 4 d 0 Ln U co co U d 0 C.) ° LI- RNN m a w O O Q < 0_ C!) 60 0 a) a) a o a)a ) rnrn a > j c 0 0 0 w z oz 1 1 Q W r CO `- Q W N lL R MNNN wwCI p w LY y o � Z o 7 :9 0 W W w W O m O p OXDEW E W J J J W 0_ < < 110_ 0 (/) LL II LL a s a) E m z r c- r co co co co co m a_ d d 0 J U' N0 W a- m m m m Q Q co co U LL co U) d tY • • • Well: B-31 B-31 IA Cement Squeeze Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Wade Boman (907) 564-4647 Reservoir Engineer: Vivek Peraser (907) 564-5306 History B-31 was swapped to PWI on 4-4-15. The well failed an MIT-IA on 6-26-15 and was SI. The IA was pressured to 1000 psi, the OA tracked, and a LLR of 0.3 BPM @1000psi/815psi IA/OA was recorded. A LPE (Leak Path Evaluation) was performed on the IC packoffs indicating that either the primary, secondary, or both IC packoffs were leaking. Note that this was done before the deeper IA x OA leak was discovered and thus in retrospect it was impossible to determine if both seals were leaking or the test was a false negative for one of the seals. A press/temp/acoustic LDL was performed on 12-28-15. Diesel was pumped down the IA, with returns up the OA, with a differential of 850 psi (IA 980, OA 130), at 3 bbl/min leak/pump rate. The deeper IA x OA leak was confirmed @ 2642' MD. An OA cement job was planned and sundry approval was received for this work. However, sufficient injectivity into the OA shoe could not be established. The revised plan is to perform an IA cement job to seal off the PC leak. Current Status The well is currently classified as "Non Operable" by BP due to the IA x OA leak. The well is currently shut-in until the leak is fixed. Job Economics Over the next 10 years, there are 260,000 bbls of oil estimated to be recovered as a result of getting this well back on water injection. Current economics do not support a full blown rig- workover, therefore this alternative integrity repair is proposed to regain operability of the well. Objective The objective of this job is to cement the IA to seal-off the IA x OA leak and regain operability of the well. Cement will be pumped down the production tubing and circulated up the IA to above the PC leak. The intent is to have cement in the IA from the production packer to -500' MD. • •Post-Job Evaluation This well is an injector so an AA will be applied for with the following proposed evaluation criteria: ➢ MITIA and MITT to maximum anticipated injection pressure ➢ SCMT to confirm Top of Cement (TOC) • Temperature Warmback Log & Water Flow Log to verify no flow behind pipe Long-Term Integrity Monitoring ➢ Record WHPs and Injection rate daily (includes pressure-monitoring of the 500' deep Inner annulus). ➢ BPXA will submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report. ➢ 2-year (biennial) MITTs and MITIAs to maximum anticipated injection pressure. ➢ Maintain IA pressure below 2000 psi normal operating limit. ➢ The well will be immediately shut-in and the AOGCC notified if there is any change in the well's mechanical condition. ➢ After the well is shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. 2 • by DRAFT AA BP Exploration (Alaska) Inc. requests approval to continue water injection service with a cemented IA into Prudhoe Bay well B-31 (PTD # 1910460). Well B-31 currently has a production casing (PC) leak at 2642' MD which will be repaired, per attached Sundry, by cementing the IA and bringing estimated top of cement (TOC) to -500'. An initial cement evaluation log (SCMT) will be run to verify cement placement after the initial IA squeeze as well as a temperature warm back and water flow log (WFL) obtained to verify no flow behind pipe. An MIT-IA and MIT-T will be conducted to 2500 psi to confirm the success of the repair and that both the tubing and production casing are competent. If continued operation of the well is granted, the inner annulus operating pressure shall be maintained below the MOASP of 2000 psi. In summary, BPXA believes Prudhoe Bay well B-31 will be safe to operate pending the successful completion of the planned work and testing outlined in the attached Sundry, and requests administrative approval for continued water injection service with a cemented IA. If you have any questions, please call me at 564-4303 or Jack Lau/Adrienne McVey at 659-5102. • i Prudhoe Bay Well B-31 Technical Justification for Administrative Approval Request July 19, 2016 Well History and Status Prudhoe Bay injection well B-31 (PTD # 1910460) has a PC leak at 2642' MD which prevents current injection service. Over the next ten years, there are 260,000 barrels (bbls) of oil estimated to be recovered as a result of restoring this well to water injection service. Current economics do not support a rig workover, therefore cementing the IA as an alternative integrity repair option is proposed in the attached sundry. A SCMT will verify cement placement after the initial IA squeeze. A temperature warm back and WFL will be obtained to verify no flow behind pipe. Lastly, a MIT-IA and MIT-T to 2500 psi will be performed to confirm the success of repair and that both the tubing and production casing are competent. Recent Well Events: > 06/25/15: MIT-IA Failed, could not reach test pressure > 06/26/15: MIT-IA Failed > 07/26/15: PPPOT-T/IC Failed > 10/04/15: LPE on the IC packoffs indicated one or both seals are leaking > 12/28/15: Leak detect log finds PC leak @ 2642' MD > 04/24/16: PC leak between IAxOA has LLR of—0.10 bpm @ 2470 psi Barrier and Hazard Evaluation The primary and secondary barriers systems consist of the tubing and production casing and associated hardware. A SCMT will verify cement placement after the initial IA squeeze. A temperature warm back and WFL will be obtained to verify no flow behind pipe. A pressure test of the tubing and production casing will be performed to 2500 psi pending successful sundry repairs, demonstrating competent primary and secondary barrier systems. Pressure on the inner annulus is maintained below the normal operating limit of 2000 psi when the well is on-line. Proposed Operating and Monitoring Plan 1. Allow water and injection service. 2. Record wellhead pressures and injection rate daily. 3. Submit a monthly report of well pressures and injection rates to the AOGCC. 4. Perform a 2-year MIT-IA and MIT-T to maximum anticipated injection pressure. 5. The well will be shut-in and the AOGCC notified if there is any change in the well's mechanical condition. TREE= 6'X 7'CW FLS • • ww w n= 13-50T MC [� Current SAFETY NOTES:1125 I ADIGS AVERAGE 125 ppm ACTUATOI= BAI ER C LJ- UN WELL A SSSV'WHEN ON IIB_REV= 67.72' AIL BF_ELEV= 39.87' KOP= 4900' —Oak= _ 94 i/I T 2107 --17'076 RFS FAP_D=5 963' i Osler 7YI: MDT SS / 20'tX]MUCTO ,13=? —I 170' 1 13-318'CSG.Balk Nilo.CYFE 0=12.415' —I 26B7 [-A1` & Iilimuse a= 31113"la 2102' 4-1R- SSSV NIPPLE 5 x. 8806' —9-5w A T BIM SAKI Plot tr/TBG ANCHOR SEAL HP,I)=6A' ■ 1Ei 885W —7'0RPSP 0=5_963' 7'-1136.28/t.LSO,(MS._0303 bpf.0=6278' — 890C I =" 8906- I—7'MANN SEAL ASSY 70P OF 7-1/04 H s9os' ,,� I 8897' HELLO Hill Ti IOGC�12r29m 1 8906' 11 9-5W X 7'TW HYORAIRC HANGER. . vr1TLBACK SLY,0=? 9-515'CSG.47#.HENS.NESS.0=sir — 9175' -, k •••9294'SLU —F6Ft 7'FR FLLJG BODY.0AL 29'(10115/15) PENFORATDM SUMMARY 9309' —7•MARKER i -CHIT REF LOG:ATLAS-BHCA,05,09191 ANGLE ATTDP PEI F: 30'6)9290b •• •' 9375' —�7O"OF CIT(06809035)� Now ReierPlodsc s DB Tor iidoriiai peri dais ��ji SPE SW OITEI WAL Op&Sgz GATE 0141•1+ ��,1l�j { 0 MAW 3-3111' 4 9290-9370 0 05131192 _ _ 9405' —IMP OF snrn 010,2035)4' 4 9370-9354 C 06109195 4' 4 9398- 9454 C 06102195 I 4' 4 9460-9490 C 06102/95 7'CSG,2011.use.',ism.-030.3 bpi.O=0.276 — 9759' 9798' H/BID 7-18G.290.uses.war._0371 Ø.O=8_184' H 98411- 40:.-4 AV DATE REV BY COINIE ITS DATE REV BY COIf6ITS IWJO IE BAY IMF 06/10191 NIDE' ORIGINAL aUin_ETIUN 10102/15 GMAT] PULLED 7'IISERT(09fl6/15) HUI: B-31 02115111 IMAM] ADDED SSW SAFETY NOTE 01/29116 GTWITLH FISH(T PLUG)(10115115) PERIM-No:1910460 01117!12 TINYJO ADDED(VS SAFETY NOTE API No: 50-029-22152-00 03119/12 SET7A0 PRO PLUG(03114112) SEC 31,T11N,R14E,2105 FII 31609'EEL 04105 12 TPClAO TREE C8((04,04112) 04111/12 TxW1.)PULL PRO PLUG(O4400E112) BP Exploration(ce) 3 • • TREE= 6'x r Crr FLS ,lYaLIG40 13-511-PC B-37 FroSt IA Cement - , 5" 1 ACTUATOR BAKER C IELEV= 67.77 IAB_ BF_EI EV= 392T P= 4900' I 1 KO — '--- r C N 10 Hex A = 35'a 8429 t� - 1D Daiwa 197= 9425' /% f'"'\ ` DaTVD ` = aa00'SSLJ r 20'GOFi]uC10rR D=? -I 110' Y 13-VIr'DSO.6.NF60.GYI-L D=12415' H 2682' t---- k Minimum D= 3213"@ 2102' 4-1/2" SSSV NPPLE 8806' -9-518'x r OKR SABI PIR wilBG ANCHOR SEAL HP,D=640' I 88.58' -rOHS RP D=5.963' r 1 Lao.u+S._0363 bpf,D=6_276' - BMW 8906' 1--r Dc>lerr SEAL ASSY OF r DR ]-1 11906' 1 116,-- Mr H[Lam n-Lame)12899 I 1 8906' I—{ssrr x r TW HYDRMILIE HANGER IIair T>ESACK SIM,U=? 9-5aP GSC.470_NIaOS.MSS.13=8_981' - 9175' -, , ilk jI -9294'SLr I-Mat rill MUGS BODY.am_29'[10x1515) PERFORATDN SIIWARY 9309' -T WAXIERrOrfr REF LOG:ATLAS-BHCA,05479191 ANGLE ATTOP WIRE 30"Q 9290 '' #14/1 9375' IOP OF CHEW[ ) Nom Reterlo MANX=DB for it irkal pert dab •11 ►. SPE SPF INTERVAL Opa&Sgz DATE v 3-318' 4 9290-9370 0 0531192 {x, 9405' --Our OF SlIFO MUM) 4' 4 9370-9384 C 06109195 4' 4 9398-9454 C 06x02195 4' 4 9460-9490 C 06102195 r CMG.2611_use.NSGc._0383 bpi.D=6.276 - 9159' 4-.411414". y4 I 9798' H"'D %Iw r TEG.2911 L-$OS_BUTT__0371 bpf.D=6.184' H 9B4W DATE REV BY COTTERS DATE REV BY C) ITS PRUDHOE BAY IMT 114l2ti91 IMF OIHGlIAL COMPLETION 10102N5 GAMIC PULLED r I1SEKT(0916r15) WF11- B-31 021511 =DM ADDED SSSV SAFETY NOTE OV29F16 GTYIIIILH F6H(r RUG)(10115x15) PERIM-No:1910460 01/17112 TIMID.ADDED IQS SAFETY NOTE , API No: 50-029-22152-00 0311912 SET1'N D PRA RUG(03114/12) SEC 31,T11N,R14E,2109 FOC 81609 FEL 0440512 TPC/MD TREE CA)(04104/12) 04111/12 MEW RN1 PRA RUG(04408/12) IF Exploration(Alaska) 4 S 0 TREE= 6-xrcw RS W8111EAL 13-5.6'BIC SAFETY NOFES 025 REI10Bt S MIRAGE 175 ppm ACTUATOW RAI®iC B-31 Proposed P&A '"1MIONIll. WELL REQONES ASSSV INNEN ON IGO REV= 67.77 INE BF_ELEV= 3&67' - IMP= 4900' ' .47 - "' Cement Plug#3 circulated down tubing,through mut AN*= a . tubing punches and up IA from-500' MD to Dalmt 10- 9425' Dallm1 sew ss surface zo-C13013UCTOR.U=7 110' zr ' HI ' d,„`o,,p�a ` Cement Plug#2 Circulated down tbg,through 13318'CSG. 11180.DYFED=1z41s 2082' perforations @-1800'M D and up OA to surface iliftu. I= 3_013”(22102' 1- t " Cement Plug#1 pumped FB or laid in w/CT 4-112' SSSV NPPLErit :41: attic Ai ►Z� .-, 8506• -9-515 x 7-esaz Sm._Raz ,; 015 wHEIG ANCHOR SEAL 1r,u=6A' 1 8050 -7'0115RM n=5.963- 7'1BC3.amt.Lao.1J4S._0383 bp&U=6276" - 8906• X06• I-7-D1>W(SASSY ICC OF 7-Lt I-1 • 1:4. - u TILoom)iomm I !lit 401 --N tot t.,1A 5906• Issor x T-rigHYORAIILC BANGER lI 1EBACQ SLV,D :::171:::: 9-510'CSG.47lFR,MSOS.MrSa D=81' — 91T.�i iiteigiifil: N -9294•sLN -F1S1t 7-FR FLOG Boar.aAL 29'(1OnOn5) IFNrORATION SUI■{ARY [::::::,,,1,1,' 9309' —T i o u .1314T REF LOG-ATLAS-161CA,05109191 ANGLE ATTOPP 30' 9290 �•i*�:•,�•;•y 9375. H'° °F�( Nom Rekrb P1o�iarioa CO For ural N• 41 M+r M1ii�1w,.1 peal t444:►�t.1*44: 1011 SUE SPF NFHNAL N 4f 3-315 4 9290-9370 0 0531 :�+'*►mil �� 9405• 1113113 of SAW Iar2pas7 4' 4 9370-9354 C 06109195 4' 4 9355-9454 C 0610295 4' 4 9460-9490 C 06102195 [Type a quote from the document or the summary of an interesting point. You can position the text box anywhere in the document. Use the Drawing Tools tab to change the formatting of the pull quote text box.] T CSG.20N.480.NSCC,_0383 bpf.O=6276 — 9750 BG. / ease) 97B' -imp9U I 7-1 290 1.-aos.BUTT.A371 bpf.13=6_184• H MAW • Mi� DATE REV BY COINIENTS DATE REV BY CONNEI1T5 PRUDHOE BAY IMT NOM 914E OW6NAL CO IP'LE ION 10102/15 GRIMM PURLED 7'NSERT(09/16115) WELL 11-31 02!15/11 I81A0 MOW SSSV SALT TY NOTE 01129/16 GiMORN FNII(J•PLUG)(10/15115) n3an-Na'1910460 01117112 71111/.110 ADDED MS SAFETY NOTE API No: 50-029-22152-00 03/19/12 SET7J1110 PRO PLUG(0314112) SEC 31,T11N,R14E,2105 FIl.31609'FH_ 04105112 TPC13110 TREE CMU(04104112) 041112 IXWEIND RRL PRO PLUG(04105112) BP Exploration(Alaska) 5 • S Composite Cement Retainers OIL TOOLS ire 1l11Nat10NA INTER VENTIONLESS CCRTM INNOVATION REVEALED The Interventionless Cement Retainers designed to eliminate the need for tubing to accomplish remedial cement squeeze operations,while significantly simplifying the process and a pros rig reliability By adapting existing te hnologiessuchasfloatvalvesandwiperplug systems Magnum Oil Tools has tailored a new way of imps rving efficiency using techniques that have already stood the test of time in our industry This tool may be run via wireline,coil tubing or rig ionve,ance Once the lnterventioniess Cement Retainer has been set,and the setting assembly has been retrieved to surface,the full required amount of cement mai be"bullheaded'directly into the casing.A wiper dart system is then deployed to displace the cement through the retanwr and squeezed into location Once the wiper plug has reached the tool,it will create a seal,and a ratcheting mechanism will lock it In place Thiswill effectively stop communication between the casing below the retainer and casing above it. As a failsafe,the Interventionless Cement Retainer is equipped with a float valve that prevents communication up through the retainer in the absence of the wiper plug if cement volume is over calculated,communication is screened off ar the annulus otherwise stops taking cement, this float valve will prevent what has been pumped in so far from flowing back:through the tool w&hout the need for thew iper plug to be landed on the retainer FEATURES Low temp and high temp rnatenals caiducrve to a wide range of elrnlr_.nments • Improved reliability through simplification Millable oast iron slips • High differential pressure rating • Significant cost savings by ehrninatingthe need for tubing • Patent pending technology 'Magnum Oil rods recommends the use of the Interventionlea MagruinOisk'•for smbt.ns operation,.as Iona as the pressure control cowman)and.or aperntor have procedures in plisse to scone/cantral the well in the rrlikery eaent of tool faikire. 10 S • , . Mf NU Composite Cement Retainers OIL TOOLS imittepiaitisioal. Weight Min Flow ie h O.D. Range O.D. ID, Area ngt Setting Low Temp/ Low Temp/ Mid Temp/ High Tempt .nc?, it,"•, - - - - - - -,.- Tool Low PSI High PSI High PSI High PSI 'kerro -..7 -,- 9 5-13 5 3 53 -. _ . 4 5.., ...- ... , 1;:-2:'L) 410 '27'..,-1.9 a - 2,4 5751. '73- ,214 _02 45.3- 59-5 •..E 7: ,-;.‘S.,: ,151,1 • - .. . s:c.,cli--•!-....1.7' -,-.,,:„.)ino„,r,,,,i5,r:,:,rr•e-a,:-.-tr:laj.t. I' if S-31 -Th IA _ �re antes - usim t,24rr5 Uaik16 ON22ra aGazis 35,23.� Job Notes • IA x OA leak @ 2642' MD. 2-3 bpm @ 800-1000 psi (since this LLR was established the leak apparently packed off and went down to -0.1 bpm @ -2500 psi) • PPPOT-IC failed. LPE test inconclusive (due to PC leak below) but indications are that one of the seals has integrity because the surface pressures on IA and OA do not track during pumping operations (see pumping WSR of 12/31/15) . Cement Calculations IA Cement(packer to 500' MD) 212 Bbls Total cement to pump 212 Bbls Key Parameters Ppg: 15.8 ppg Class G — Mix on the fly Slurry Temperature: between 80° and 110°F API fluid loss: 40 - 200 cc Thickening Time: Minimum 5 hours Compressive Strength: 2000 psi in 24 —48 hours Cement thickening time: Mix on the fly Activity Time(hours) Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination 0 Safety 2 Minimum required thickening time: 5 6 410 • Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 140 2800 2:00 140 2000 5:00 140 200 10:00 46 200 16:30 42 200 24:00 39 200 Volumes: top volume MD bot MD Size ID bbls/ft. Ft. bbls 9-5/8"47#x 8.681" 9-5/8" x 7"annulus 0 8800' 7" 26# X 7" 0.0256 8800' 225 7"tubing , 0 8800' 7"26# 6.276 0.0383 8800' 337 Eline/Fuilbore 1. Set 7" composite bridge plug @ -8780' MD (middle of first full joint of tubing above production packer). 2. MITT to 3000 psi to verify the CBP will hold the pressure needed for the cement job. 3. Punch tubing w/ 5' tubing puncher from -8758' - 8763' (across the top collar of the first full joint of tubing. Note indication of TxIA communication in AWGRS. 4. Set 7" Magnum "Interventionless-CCR" cement retainer (sourced through Baker) @ -8739' MD (middle of second full joint of tubing above production packer). Note: All depths reference attached tubing tally dated 06/28/91. 7 FuUbore • 1. RU wiper plug dropping assembly on the tree with pump rigged up to pump in below it, taking returns from the IA to tanks. Also, rig up in a way that returns can be diverted upstream of the tree (to make sure the water spacer ahead of cement can be diverted to tanks and not pumped down the well). 2. Pump the following schedule of fluids down the tubing with returns from the IA @ max rate achievable staying within a maximum pressure of 3000 psi: ➢ 560 bbls of 160F heated diesel ➢ FW spacer as needed (divert ALL of the FW spacer upstream of the tree so that the interface is diesel/cement. If the FW spacer were to be pumped into the well it would end up @ 500' MD in the IA and eventually freeze and collapse tubing). ➢ 212 bbls of Class G cement ➢ Drop wiper plug ➢ 337 bbls of 140F pre-heated 9.8 ppg brine (pre-heat the brine so that it can be pumped at a high rate; 2-5 bpm is preferred to get cement in place before it sets). ➢ Slow pump rate to minimum as the last few barrels are pumped and bump the wiper plug to 100 psi over circulating pressure. Note that the hydrostatic pressure difference between the cement in the IA and brine in the tubing will be -2350 psi so expect to need -3000 psi towards the end of the job. 3. If the plug was bumped, bleed pressure off of the tubing to 0 psi but bleed no more than 5-bbls back to achieve this. If more than 5 barrels are returned before pressure is zero then assume that the retainer or wiper plug are not holding pressure and leave the remaining pressure on the tubing to keep cement in place. RDMO. 4. If the plug was not bumped, then leave -2500 psi on the tubing to keep cement in place and RDMO. Note: The 9.8 ppg brine will suffice as freeze-protection in the permafrost. The crystallization temperature of the brine is -0 deg F. If the job is pumped during winter months, however, a couple barrels of diesel will need to be substituted for the brine as the last few barrels are pumped to freeze protect the tree against ambient surface temperatures. *Note: There are two reasons for the heating the diesel: 1. The cement in the IA acts as an extended packer. Tubing movement models indicate that heating the entire wellbore to -140F before setting a packer on a rig is the optimum temperature for locking the tubing in place in PBU buckling when the tubing is heated up via producingor injecting). Heatingthe J 9) entire wellbore for this type of job to 160F will approximate this (wellbore fluids will cool before cement sets). 2. Heating the entire wellbore helps the cement to cure. There have been p a couple of IA cement jobs where fluids were not heated prior to cementing and the cement took much longer to cure. In one case it took about 2 weeks before the well would pass an MITIA. 8 DHD • 1. WOC 7 Days and MITIA to 2500 psi. Coiled Tubing (2") 1. RU with 7" BOP stack or plan to pick up the 7" milling BHA hanging below the 4-1/16" BOP stack. 2. Mill out retainers, cement, and CBP with 5.90" Mill or Mill + Underreamer. Push remnants past the open perfs to TOC @ 9375' MD. Slickline/Fullbore 1. Set Tubing Tail Plug in R-nipple @ 8858' MD. 2. MITT to 2500 psi. 3. Memory SCMT to locate bottom and top of cement in IA. 4. Pull TTP. E-Line 1. WFL and temperature warmback log to indicate any flow behind pipe. DHD 1. After Injection has stabilized, perform AOGCC witnessed MITIA to 2500 psi. Well Integrity Engineer 1. Add Biennial MITTs and MITIAs to AnnComm for additional monitoring of the well integrity. 9 . • • , ` 3 ' TUBING SUMMARY 6- 2e-91 (atop IVO 7" IJ4S L-80 USED TBG. 26 LBS.iFT. WELL No. B-31 NABORS 18E KB: 25.6' ATS 240 JTS. ON RACK 228 JTS. RAN 12 JTS. OUT 9296 FT. ON RACK 470.6 FT. OUT LAST CSG: 7". L-80. NSCC LINER ITEM LENGTH TOP BOTTOM 7" DUMMY SEAL ASSEMBLY 6.53 8,899.68 8,9Q6,21 /nit- JT 1 1 JOINT 7" IJ4S 39,58 8,860.10 8,899.68 7" OTIS 'R' NIPPLE 1.74 8,858.36 8,860.10 JT 2 1 JOINT T' IJ4S 37.23 8,821 .13 8,858.36 X/O 7" TC4S X 7" NSCC 3.90 8,817.23 8,821 . 13 MILLOUT EXTENTION 6.64 8,810.59 8,817.23 9-5/8 'SABL' PKR WFTBG ANCHOR 5.00 8,805.59 8,810.59 X/O PUP 7" NSCC X 7" TC4S 6.23 8,799.36 8,805.59 JTS 3-175 7", L-80, 1J4S TBG 6,671 .12 2,128.24 8,799.36 PUP JOINT TC4S 1 1 .1 7 2,117 07 2,128.24 SSSV LANDING NIPPLE/FLOW COUPL 14.89 2,102.18 2,117.07 , PUP JOINT TC4S 12.75 2,089.43 2,102.18 JTS 176-229 7", L-80, IJ4S TBG 2,048.75 40.68 2,089.43 (LEAVE OUT JOINT NOS. 184 + 214) 1.,, SPACE OUT PUP JOINT 'A' 10.6C 4.1. to ' 30.08 40.68 XIO 7" TC4S X 7" NSCC 2.80 27,28 30.08 7" FMC TUBING HANGER, CCL 1.68 25.60 27,28 RT = TS 25.60 0.00 25.60 1al tiieta LE. ©uT R., p a1 S, r0 © /V Td elF • l0 • • IGNUMComposite Cement Retainers OIL TOOLS INTERvENTIoNLEss cc TM INNOVATION REVEALED The Interventionless Cement Retainer is designed to eliminate the need foi tubing to accomplish remedial cement squeeze operations,while significantly simplifying the process and improving reliability,By adapting e<isting technologies such as float valves and wiper plug systems,Magnum Oil Tools has tailored a new way of improving efficiency using techniques that have already stood the test of time in our industry This tool may be run via wireline,coil tubing or rig conveyance.Once the lriterventionless Cement Retainer has been set,and the setting assembly has been retrieved to surface,the full required amount of cement may be"bullheadeddirectly into the casing.A wiper dart system is then deployed to displace the cement through the retainer and squeezed into location.Once the wiper plug has reached the tool,it will create a seal,and a ratcheting mechanism wit lock it in place This will effectively stop communication between the casing below the retainer and casing above it As a failsafe,the Interventionless Cement Retainer is equipped with a float valve that prevents communication up through the retainer in the absence of the wiper plug.If cement volume is over calculated,communication is screened off,or the annulus otherwise stops taking cement, this float valve will prevent what has been pumped in so fat from flowing back through the tool without the need for the wiper plug to be landed on the retainer 1111, FEATURES • Low temp and high temp materials conducive to a wide range of environrrents • Improved reliability through simplification • Millable cast iron slips • High differential pressure rating • Significant cost savings by eliminating the need for tubing Patent pending technology -mworr,011 Tools recommends the use of the Interventionless MagrurnDiskfor snklabing opernPons,as long n the pressure ,-.ccrtrd company amd/ce operator n&e proceelures in pine re seculeicontrol the well in trc.likely event of tool failure. 11 III • +i AG Composite Cement Retainers OIL TOOLS IMllRMATIONAL O.D. Weight Min Row Length .cr. Range On. I.D. Area Setting Low Tempi Low Temp/ Mid Temp/ High Temp/ q`t mch^ Tool Low PS/ High PSI High PSI Hugh PSI ,,,rr:. .._ , irr6 tamnry 114.1-20. 9403) :rtwyyaa,.." 4 "2 .._..,,, ._.., 0EIS a.50 j 24.45 'Ad." rufa.71 22.29 93Er7.9i 1621C1 ! B to&410 /5 4171 344 j qtr Onov,r i CC22 5-25.47 1741 .,sC"'F 250* 300'[. A00 F U:54 DPNCSt IOKSI 10464. 14 0 60 !2 88 46.Et# 3T:2.ra orrci arts"C7 I2'4ti. 155.21 ad X68.60 5-112 is 50-20 00 ! 430 1.25 - 1.23 242 I Me I I:23.1-29 80 009 Z1 I (37` ) t d.37 ; 4514.71 4anex�m Yeas,. Blue5iue ` a»g rw'` C aTaesite/ Conrt ic e,+ ua�twrs ' 23.00-2S 40 4113 1 -411 PlIsile! 'Name mitim V 14rati 934 2-42.31 004 i Fibber 420 E166Axax e.r Etastoniet Eta is e; El1astatntf Ta'3-330= 5_.65 i 2 tis 3-29.81 415611 250 4.51 V.50 37 71 4 21 0,320575 C3T55 9 C598 50' 1 5.75 ,'34.2-4160 3461I i I Casing Specs are arx,ordir*g to API'Tr rilr'giCasil>,g IItame saorl Citwt Ixriiorrsat 12 • • Carlisle, Samantha J (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday,August 03, 2016 1:57 PM To: Carlisle, Samantha J (DOA) Subject: FW: BP IA Cement Sundries From: Loepp, Victoria T(DOA) Sent: Tuesday, August 02, 2016 1:44 PM To: Ryan.danielObp.com Subject: BP IA Cement Sundries Ryan, The following sundries for IA cementing have been submitted by BP for approval. This work requires waivers from our existing regulations. Specifically,for the production wells 20 AAC 25.200(d) requires that all producing wells be completed with suitable tubing and a packer. And for the injection wells 20AAC25.412(a) requires the well be completed with tubing and a packer and that the packer be placed with 200 ft measured depth above the perforated injection interval unless the AOGCC approves an alternate design or packer setting depth. The AOGCC is viewing your proposed work as making the existing tubing a casing string since almost the entire annulus would now be filled with cement. Therefore,the AOGCC believes the best approach is to establish pool rules that outline the criteria for when and how these types of completions can be used. We will not be approving these sundries. We recommend that BP make a request for modification to the respective Conservation Orders and Area Injection Orders and proceed through this public process. PTD Sundry Sundry Sundry PBU PTM P1-21 193-059 316-375 316-371 316-264 PBU B-31 191-046 316-399 316-368 316-270 PBU M-13A 201-165 316-376 316-369 316-259 PBU Q-06A 198-090 316-372 316-370 316-233 PBU E-07A 201-034 316-380 316-288 Regards, 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.Loem@alaska.gov 1 0 0 •91 '0 4-k<„,, �'" Ili wQ\I'//�*s� THE STATE Alaska Oil and Gas AA-- �—;�, of Conservation Commission , ,_ ALAS <:A t Simi i� 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS ' Fax: 907.276.7542 www.aogcc.alaska.gov FEE 2 Aras Worthington SCANNED if Wells Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool,PBU B-31 Permit to Drill Number: 191-046 Sundry Number: 316-080 Dear Mr. Worthington: 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, ,920--t - __ Cathy . Foerster Chair DATED this /v day of February, 2016. RBDMS c-L FEd 1 1 2016 STATE OF ALASKA y '' • ALASKA OIL AND GAS CONSERVATION COM ON • APPLICATION FOR SUNDRY APPROLS FB Q 3 2010 20 AAC 25.280 o TS G/{lpjg? I 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well p. Operations shutdown 0 I Suspend ❑ Perforate ❑ Other Stimulate 0 Pull Tabing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other OA Cmt Sqz RI 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: Exploratory ❑ Development5. Permit to Drill Number: 191-046 3, Address: P.O.Box 196612 Anchorage,AK p ❑ 99519-6612 Stratigraphic 0 Service 0- 6. API Number 50-029-22152-00-00 7, If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No p PBU B-31 - 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028310 . PRUDHOE BAY,PRUDHOE OIL , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9840 9228 9375 8824 9375 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"Conductor 32-112 32-112 Surface 2646 13-3/8"68#NT-80 31 -2678 31 -2678 5020 2260 Intermediate 9144 9-5/8"47#NT8OS 29-9173 29-8650 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 7"26#L-80 L-80 P7-8912 Packers and SSSV Type: 7"Baker SABL-3 Packer Packers and SSSV MD(ft)and TVD(ft): 8811, 8340.72 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ❑ Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program E] BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ESI. 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG p • GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Wells Engineer Signature / Phone +1 907 564 4102 Date COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: . 31 co -OM Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance 0 Other: 'tD,� a fr �a b, f, -e cl � tGcfT W / � t SS f!/ AA L J— !.fi TC2 I Y _ Post Initial Injection MIT Req'd? Yes I No ❑ Spacing Exception Required? Yes 0 No d Subsequent Form Required: /(' — 40 4 i'/_,i4 /� I APPROVED BYTHE Approved by: �L- COMMISSIONER COMMISSION Date: 2_/Q_ /c.. Pr z/5//L ORIGINAL Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate RBDMS LL FEB 1 1 2016 -- -11> z - 47"-.4' • a 0 0 0 0 cO Co — N N f` �t O cr p N NI- CV tN f"- CO V O CO N r- N CO OOr- co � CO O r CO CO r O N ' O CO o- N 'cf' N CO O O Cb H N O) I- M M N d' r- N CO O N co co f-- CO N N O Mr )O �- N- coO O N 6) O) O) co O p i .- M N- Nr- O O O I� 01 M C) C N CO N M � Y.1 H a ou) L co 0 ° I- cO000 C) OZHcococo UDO N N N V b r• N M O t r co O N co c co CO O N O) co LtW — C O o •NUU W U 0 LL X W M Z Z W W W m ODF' ZZD O w Z J J E- • • a) N fi m 'ct CO CO CO O N- CO O Q O N N 4 w N M CA N p 00 CO CO 0) CO CO CO CO a. O I- V. N CO t I- O M O C1 O O 4 CO ❑ N N V CS) W N- CO CO CO O CO CO CO CO 0 w ❑ m I- 0 O a m 0 p Q O O O Y Y CO CO CO U G H LU 4 CU LU pNC J J J as cc , O CO CO Cr) J QJ Qas M co t cUU UO O) a) O) a) _ Z Z O ❑ ❑ a CD = ❑ ❑ wa Z ❑ _ 0 C) 0 W Z Q Z CO ma 0 Cm -5 (04000o M QC) N- C) (0 O m (N CO CO Nt C) O) O) Cr) Co L N a _ 0 0 a J a O 00) 0) 0) 0) 0) CD a. O U c .2 i . N N io 0_ Lu o < 0_ 0 t m a r F- o rn 0) 09 09 ❑ > :-9 0 C O) CA O CA w J J z O v- Z u- a a ¢ W O W O. LO CO CO CO Q ❑ p J p 0J J w w tL W 0 m ❑ rY ❑ c:Lw J J ¢ Q W W < ¢ ro a mcn LL U w cn a a) E 'o z Cn CO CO M CO m a a a O J CJ' O W d 00000000 ¢ ¢ m m w LL cn m a a '.` • • B-31 OA Cement Squeeze Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Wade Boman (907) 564-4647 History B-31 was swapped to PWI on 4-4-15. The well failed an MIT-IA on 6-26-15 and was SI. The IA was pressured to 1000 psi, the OA tracked, and a LLR of 0.3 BPM @1000psi/815psi IA/OA was recorded. A LPE (Leak Path Evaluation) was performed on the IC packoffs indicating that either the primary, secondary, or both IC packoffs were leaking. Note that this was done before the deeper IA x OA leak was discovered and thus in retrospect it was impossible to determine if both seals were leaking or the test was a false negative for one of the seals. A press/temp/acoustic LDL was performed on 12-28-15. Diesel was pumped down the IA, with returns up the OA, with a differential of 850 psi (IA 980, OA 130), at 3 bbl/min leak/pump rate. The deeper IA x OA leak was confirmed @ 2642' MD. Current Status The well is currently classified as "Non Operable" by BP due to the IA x OA leak. The well is therefore currently shut-in until the leak is fixed. Objective The objective of this job is to cement the OA (9-5/8" x 13-3/8") annulus, repair the IA x OA leak, - and make this well operable. Cement will be pumped down the OA from surface in two stages (if needed). The goal is to have cement in the OA from the 13-3/8" casing shoe to surface. Procedural steps Fullbore 1. Establish injectivity rate and pressure with diesel down the OA and into formation. Cementers 1. RU to the OA. 2. Pump enough Class G cement to fill OA to surface displacing OA fluid into formation. SI and allow cement level to reach equilibrium. 3. WOC to build strength. 4. Pump a second cement job to refill OA to surface (if needed). DHD 1. MITIA to 4000 psi. DHD (contingent steps - if Mfails) • 1. Perform Leak Path Evaluation on IC Packoffs if MITIA fails. 2. Perform sealant treatment on IC packoffs if both primary and secondary packoffs are found to be leaking. 3. MITIA to verify packoffs are sealed/repaired. Operations 1. Put well on injection. DHD 1. Perform State witnessed MITIA to 2500 psi after injection has stabilized. 2 TFC= 6"X 7"CNV FLS III ___.V __. ------- WB LHEAD 13-5/8"FMC SML ANOTES:H2S READINGS AVERAGE 125 ppm ACTUATOR=VBAKKER -3 1 31 WHEN ON MI. WELL REQUIRES A SSSV WHEN ON BF.E EV= 39.87 ` B KOP= 490Y I \ htax Ante= 35°@ 8429' Datum MD= 9425 © 4 I 2102' _17"OTIS RPB NP,D=5.963" Datum TVI: 8800'SS LO"CONDUCTOR,D=? 1 110' (0 Ar21 S C 7. [1 .3-3/8"CSG,68#,NT-80,CYHE,D=12.415" --I 2682' l'"',N I 1 Minimum ID = 3.813 "@2102' 4-112" SSSV NIPPLE i 1-! ►�� 8806' —9-5/8"x 7"BKR SABL PKR w/TBG ANCHOR SEAL NP,D=6.0" 8858' —7"OTIS RNP,D=5.963' 7"TBG,26#,L80,U4S,.0383 bpf,0=6.276" 8906' 8906' --17"DUMMY SEAL ASSY TOP OF 7"UV H 8906' ■ ® 8897' —ELMO TT LOGGED 12/29/91 8906' —9-5/8'X 7'TW HYDRAULIC HANGER w/TIEBACK SLV,D=? 9-5/8"CSG,47#,NT80S,NCSS,D=8.681' --i 9175' -J I PERFORATION SUMMARY f 9309• —7 MARKER JOINT REF LOG: ATLAS-BI KA,05/09/91 ANSI F AT TOP FI32F: 30°@ 9290 .fvv♦iri�+I 9376' H TOP OF CEMENT(06/09/95) Note:Refer to Production DB for historical pert data 1��+,+����1 SIZE SPF NTERVAL Opn/Sgz DATE 1�0.�.01 3-3/8" 4 9290-9370 0 05/31/92 •♦•• 9406' —TOP OF SAND(06/2/95) 4" 4 9370-9384 C 06/09/95 4' 4 9398-9454 C 06/02/95 111111 — 4" 4 9460-9490 C 06/02/95 I 7"CSG,26#,L-80,NSCC,.0383 bpf,D=6.276 — 9759' fli�tfl 9798' —IPE/TD 1 7"TBG,29#,L-80S,BUTT,.0371 bpf,D=6.184" -9840' DATE REV BY COMMENTS DATE REV BY COM?NTS PRUDHOE BAY UNIT 06/28/91 N18E ORIGINAL COMPLETION 10/02/15 GJB/JMD PULLED 7"INSH<l(09/16/15)_ WILL: B-31 ED 02/15/11 MB/JMJ ADDSSSV SAFEI Y NOTE PERMIT No 1910460 01/17/12 T ICIMD ADDED H2S SAFELY NOTE AR No: 50-029-22152-00 03/19412 SET/JM) PF1G2 PLUG(03J14/12) _ SEC 31,T11N,R14E,2105 FNL&1609'Fn 04/05/12 TFC1JM) TREE CJO(04/04/12) i 04/11/12 DLW/JMD RLL PRO PLUG(04/08/12) BP Exploration(Alaska) 3 • z3 � WELL LOG TRANSMITTAL --II. PROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 5atttie) ` Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2—1 900 Benson Blvd. Anchorage, AK 99508 aancpdc(a7bp.com i, , and JAN P1 Zit ProActive Diagnostic Services, Inc. ;` Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 28-Dec-15 B-31 BL/CD 50-029-22152-00 2) Signed : m ' Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, June 25, 2015 10:46 AM To: AK, OPS GC3 Facility OTL;AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; AK, OPS GC3 Field OTL; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; Glasheen, Brian P; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: NOT OPERABLE:Injector B-31 (PTD #1910460) Failed MIT-IA Attachments: image001.png;Injector B-31 (PTD #1910460) TIO Plot.docx All, Injector B-31 (PTD#1910460)failed an MIT-IA to 2500 psi on 06/25/15. The failing test proves a lack of two competent barriers and the well is reclassified as Not Operable and will be added to the Not Operable Injector report. The well shall be shut in and freeze protected as soon as possible and remain shut in pending further diagnostic work. The plan forward: 1. APE: Evaluate for LDL or secure A copy of the TIO plot is included for reference. Kevin Parks 1 2015 (Alternate: Whitney Pettus) �S JUL 0 BP Alaska-Well Integrity Coordinator ,�w�� GI/►J Global Wells �/�( Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com 1 Injector B-31 (PTD#1910460)TIO Plot • ,,.11.31 • 01ni0 OStltt O4a.S 4U'SS OSODM OM% 00WV WINS *MIS 067115 0tm11 04Str3 ON•ro 0ln S_ Imag~l~roj,ect Well History File Cover le 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. L-0 RESCAN DIGITAL DATA OVERSIZED (Scannable) [] [] [] [] Other: NOTES: Color items: [] Diskettes, No. Grayscale items: [] Other, No/Type Poor Quality Originals: BY: BEVERLY ROBIN VINCENT SHERY~INDY [] Maps: i~''~' Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~INDY Scar~ning Preparation ... x30 = t" BY: BEVERLY ROBIN VINCENT SHERYL(~INDY DATE:SI /i / Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY: Stage 2 B¥~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) PAGE coUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO BEVERGNCENT SHERYL MARIA WINDY IF NO IN STAGE 1, PAGE(S) DISCREPA~E FOUND: YES NO BEVERLY ROBIN VINCENT ~HERYL MARIA~ DATE:"~.,'~,.~~'"~, RESCANNEDBT: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: IS~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd • UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ~G, ~ ~ FILE # To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 }Fax (907) 276-7542 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 11, 2009 `~!~6~~ J~I'~ ~~ ~0~ • ~.~~ DEC 1 6 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Pad B Dear Mr. Maunder, ~s~~ ~?i~ Css Cons. Commission Anch®r~g~ {{(. ~~~b 1I ~3-~~l Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad B that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date' 12/11/09 r Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al B-O7 1700080 50029200590000 Sealed Conductor NA NA NA NA NA B-02 1961110 50029200660100 Sealed Conductor NA NA NA NA NA B-03A 1870480 50029203060100 NA 0.5 NA 3.40 8/20/2009 B-04 1700320 50029200720000 Sealed Conductor NA NA NA NA NA B-OSB 2010680 50029202760200 NA 1.8 NA 13.60 8/22/2009 B-06 1770740 50029202790000 NA 1 NA 5.10 8/20/2009 B-07 1780020 50029202850000 NA 1 NA 5.10 8/20/2009 B-08 1780410 50029203140000 NA 1 NA 6.80 8/20/2009 B-09 1780490 50029203160000 NA 0.5 NA 3.40 8/20/2009 B-10A 2082050 50029203210100 Cellar liner welded to casin NA NA NA NA NA B-11 1780690 50029203310000 NA 0.5 NA 3.40 8/20/2009 B-12 1970090 50029203320100 NA 0.6 NA 3.40 8/22/2009 B-13 1990570 50029203410100 NA 0.4 NA 1.70 8/20/2009 B-14 2090590 50029203490000 NA 0.4 NA 1.70 8/20/2009 B-15 1790190 50029203600000 NA 0.1 NA 1.70 8/20/2009 8-16 1790250 50029203650000 NA 0.8 NA 5.10 8/21/2009 B-17 1790280 50029203680000 NA 0.1 NA 1.70 8/20/2009 B-18 1820020 50029207020000 NA 1.5 NA 15.30 8/21/2009 B-19 2001610 50029207030100 NA 0.1 NA 1.70 8/21/2009 B-20 1821680 50029208420000 NA 0.5 NA 3.40 8/21/2009 B-21 1821760 50029208500000 25 4.5 BBLs 0.1 11/30/2009 1.70 12/3/2009 B-22A 2001570 50029207590100 34 6.5 BBLs 0.2 11/30/2009 1.70 12/3/2009 B-23 1970590 50029207790100 12 2.2 BBLs 3.2 11/30/2009 10.20 12/4/2009 B-24 1821400 50029208150000 NA 3 NA 22.70 8/21/2009 B-25 1821510 50029208260000 NA 0.25 NA 1.70 8/13/2009 8-26 2000570 50029209760200 NA 0.3 NA 1.70 8/21/2009 8-27 1961010 50029214710100 Sealed Conductor NA NA NA NA NA 8-28 1853030 50029215100000 NA 1.1 NA 6.80 8/22/2009 B-29 2002090 50029215230100 NA 0.7 NA 6.80 8/21/2009 B-30 2011050 50029215420100 NA 0.2 NA 1.70 8/21/2009 B-31 1910460 50029221520000 NA 0.3 NA 1.70 8/20/2009 B-32 1991180 50029221650100 NA 0.3 NA 1.70 8/20/2009 B-33 1931450 50029223390100 NA 1.2 NA 8.50 8/21/2009 B-34 1930370 50029223520000 NA 1.2 NA 10.20 8/21/2009 B-35 1931460 50029224060000 NA 0.3 NA 1.70 8/20/2009 B-36 1960650 50029226670000 NA 0.3 NA 1.70 8/21/2009 B-37 2071450 50029233750000 Sealed Conductor NA NA NA NA NA 1VIEM®I2Al®TDLTIVI ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 23, 2008 TO: Jim Regg ~~ ~~1~f~ P.I. Supervisor ~~ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC B-31 FROM: Chuck Scheve PRUDHOE BAY UNIT B-31 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ '' r-- NON-CONFIDENTIAL Comm Well Name• PRUDHOE BAY UNIT B-31 Insp Num: mitCS080722194909 Rel Insp Num: API Well Number: 50-02 9-22 1 5 2-00-00 Permit Number: 191-046-0 Inspector Name• Chuck Scheve Inspection Date: 722/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well B-31 Type Inj. T'vD ~ 8337 ~ IA 240 ~ 4000 3970 I 3970 p•T• 191oa6o TypeTest SPT Test psi 2oaa.zs pA loo tlo ~ uo uo Interval aYRTST P/F P ~ Tubing , ao ao ao ao Notes: ~~~~ ~U G ~ ~:f 200 Wednesday, July 23, 2008 Page 1 of l MEMORANDlJl\1 State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg -;-. - /.'. .,L"?t I., Å P.I. Supen isor Ke II 'l L \ \L ., DATE: Wednesda). Jul~ 28. ~OO4 SllBJECT: t\'lechanicallntegrn)' Tests BP EXPLOR...Hlr)N IALASI\..A¡ INC B-31 FROM: Jeff Jones Petroleum Inspector PRUDHOE BAY UNIT B-31 Src: Inspector NON-CONFIDENTIAL Reviewed By: ;./" C--- P.I. Supn' .:J:::> Comm \Vell Name: PRUDHOE BAY UNIT B-31 Insp Num: mitJJO..W728104534 Rei Insp Num: API Well Number: 50-029-22152-00-00 Permit Number: 191-046-0 Inspector Name: Jeff Jones Inspection Date: 7/22/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well B-31 Type Inj. S TVD 9:!:!8 I IA 3.. {¡ 2510 2480 2480 P.T. 1910460 TypeTest SPT Test psi 2085.25 I OA 210 220 2:!0 :!20 Inten'al 4YRTST PIF P Tubing 1260 1:!60 1260 1260 Notes: 2.8 BBLS 50/50 methanol pumped. 1 well house inspected; no exceptions noted. Wednesday. July 28, 2004 Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate_ SCHMOO-B-GONE Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora[le, AK 99519-6612 5. Type of Well: Development __ Exploratory_ Stratigraphic__ Service__X 4. Location of well at surface 2104' FNL, 1609' FEL, Sec. 31, T11N, R14E, UM At top of productive interval 4169' FNL, 1369' FEL, Sec. 31, T11N, R14E, UM At effective depth 4208' FNL, 1391' FEL, Sec. 31, T11N, R14E, UM At total depth 4427' FNL, 1463' FEL, Sec. 31, T11N, R14E, UM (asp's 664059, 5948546~ (asp's 664352, 5946487) ~sp~ 664331, 5946448) ~sp~ 664264, 594622~ 12. Present well condition summary Total depth: measured true vertical 9840 feet Plugs (measured) 9228 feet Effective depth: measured true vertical 9375 feet Junk (measured) 8824 feet Casing Length Conductor 110' Surface 2677' Intermediate 9147' Liner 934' 6. Datum elevation (DF or KB feet) RKB 68 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-31 9. Permit number / approval number J 191-046 10. APl number 50-029-22152-00 11. Field / Pool Prudhoe Bay Oil Pool Cement Plug Top @ 9375' ELMD. Sand Plug Top @ 9405' ELMD. Size Cemented Measured Depth True Vertical Depth 20" 138' 138' 13-3/8" 3723 c.f. 2705' 2705' 9-5/8" 1866 c.f. Class 'G' 9175' 8650' 7" 280 c.f. Class 'G' 8906'- 9840' 8422'- 9228' Perforation depth: measured Open Perfs 9290'-9384', Covered Perfs 9398'-9454', 9460'-9490'. true vertical Op(~n Perfs 8751'-8832', Covered Perfs 8844'-8893', 8898'-8924'. ~ % [. ~¢,~ F~ ~=,¢, ~, ~. ,~ Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 7", 26#, L-80 TBG @ 8900'. 9-5/8" x 7" Baker SABL Packer @ 8811 '. 7" Otis SSSV Landing Nipple without Insert @ 2107'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 04/05/2003 Subsequent to operation 04/20/2003 OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 5000 8600 Casing Pressure Tubing Pressure 653 847 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ 16. Status of well classification as: Oil _ Gas _ Suspended __ Service WAG Iniector Title: Techical Assistant .. DeWayne R. Schnorr ORIGINAL Date April 21, 2003 Prepared by DeWa~ne R. $chnorr 564-5174 SUBMIT IN DUPLICATE B-31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/06/2003 ANN-COMM (AC-EVAL AND REPAIR): AC-FLUID LEVEL 04/07/2003 SCMOO-B-GONE--SBG: SCMOO-B-GONE 04/11/2003 ANN-COMM (AC-EVAL AND REPAIR): AC-MITIA 04/12/2003 ANN-COMM (AC-EVAL AND REPAIR): AC-MONITOR 04/20/2003 TESTEVENT--- IN]ECTION PRESSURE, PSI: 653 TYPE: PW VOLUME: 5,000 BWPD. EVENT SUMMARY 04/06/03 TIO=900/250/220 TEMP=142 IA FL @ 30' (PRE MITIA). BLED IA FROM 250 PSI TO 120 PSI IN 15 MINUTES UNTIL FLUID CAME TO SURFACE. 04/07/03 SCHMOO-B-GONE TREATMENT; PUMPED 366 BBLS 16% SCHMOO MIX & 4 BBL MEOH FREEZE PROTECT DOWN TBG FROM WELLHEAD. TURNED WELL OVER TO PAD OPERATOR FOR 3 HOUR SOAK. 04/11/03 T/I/O = 750/120/220 Temp = 140. MITIA PASSED TO 3500 PSI. (PRE MI INJECTION) IA FL NEAR SURFACE. LRS PRESSURED IA UP TO 3500 PSI (BBLS METHANOL). IN FIRST 15 MINUTES IA LOST 30 PSI. IN SECOND 15 MINUTES IA LOST IA LOST 10 PSI FOR A TOTAL OF 40 PSI IN 30 MINUTES. BLED IA BACK TO 700 PSI. FINAL WHP's = 750/630/220. 04/12/03 T/I/O=750/620/220 (POST MITIA) MONITOR WHP's. 04/20/03 TESTEVENT--- INJECTION PRESSURE, PSI: 653 TYPE: PW VOLUME: 5,000 BWPD. FLUIDS PUMPED BBLS 11 NEAT METHANOL 366 SCHMOO-BE GONE 377 TOTAL Page I STATE OF ALASKA ALASKA...,IL AND GAS CONSERVATION CL,.. MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Pull Tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Plugging [] Perforate []Alter Casing [] Repair Well [] Other 4. Location of well at surface 2105' SNL, 1609' WEL, Sec 31, T11N, R14E At top of productive interval 4169' SNL, 1369' WEL, Sec 31, T11N, R14E At effective depth 4454' SNL, 1472' WEL, Sec 31, T11N, R14E At total depth 4428' SNL, 1455' WEL, Sec 31, T11 N, R14E Schmoo - SSSV Type of well: II Development [] ExplOratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE: 67.70 feet 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number B-31 9. Permit Number / Approval No. 91-46 10. APl Number 50- 029-22152 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9840 feet true vertical BKB 9228 feet Effective depth: measured 9897 feet true vertical BKB 9191 feet Casing Length Size Structural Conductor 110' Surface 2654' Intermediate 9147' Production Liner 8906' Plugs (measured) Junk (measured) Cement Plug Top @ 9375' (ELMD), Sand Plug Top @ 9405' (ELMD). Cemented 20" 13-3/8" 3723 c.f. 9-5/8" 1866 c.f. Class 'G' 7" 280 c.f. Class 'G' MD 138' 2682' 9175' 8906'-9840' TVD BKB 138' 2682' 8650' 8421'-9227' Perforation depth: measured true vertical Open Perfs Open Perfs 9290 - 9384, Covered Perfs 9398 - 9454, 9460 - 9490 8751 - 8832, Covered Perfs 8844 - 8893, 8898 - 8924 Tubing (size, grade, and measured depth) 7" L80 tubing to 8906' Packers and SSSV (type and measured depth) 9-5/8" Baker Packer (SABL) @ 8811", 7" SSSV Landing Nipple (Otis) @ 2107'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water & Gas Injector 17. I hereby certify that the foregoing is true and Correct to the best of my knowledge Signed Scott LaVoie~-~"'"~"- ~~ Title Technical Assistant Prepared By Name/Number: Form 10-404 Rev. 06/15/88 ,~ ~_~) i f~''" i Date ~/:~'"-/~ ./ ~, DeWayne ;~ch'no~r 564-517~1'--.....J;~ Submit In Duplicate 03/01/2001 03/24/2001 03/25/2001 B-31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS SCHMOO B GONE: SCHMOO B GONE TREATMENT SSSV C/O OR STROKE: PULL AND RUN ISSSV SSSV C/O OR STROKE: CLOSURE TEST ISSSV SUMMARY 03/01/01 PUMP 681 BBLS SCHMOO B GONE TREATMENT SOAK 3 HRS PUMP FLUSH 03/24/01 PULLEDISSSV SER# M-30, RAN ISSSV SER# M-48B, WELL ON INJECTION UPON ARRIVAL. CLOSURE TEST FAILED. LEFT ISSSV INSTALLED FOR MORE TROUBLESHOOTING. 03/25/01 CLOSURE TEST ISSSV. UNABLE TO DETERMINE IF DOWN HOLE VALVE FAILED DUE TO THE WING VALVE AND LATERAL VALVES LEAKING BY. GREASE CREW CALLED TO SERVICE SURFACE VALVES. WILL RETEST IN AM. Fluids Pumped BBLS. Description I DIESEL FOR PFF 2O METHANOL 681 SCHMOO 541 SALT WATER 1243 TOTAL LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE Dear Sir/Madam, Enclosed, please find the data as~%~i~e~J'below: Date: 26 June 1995 Transmittal of Data by: PRIORITY MAIL WELL N-14 (22-08-11-13) DESCRIPTION CN/GR FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PLS/STP FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 3556.05 .... 4096.02 5801.09 5830.04 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Str~ Anchorage, AK 99518 Or .FAX to (907) 563-7803 Received LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 13 June 1995 Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL B-31 (44-31-11-14) 77-'~ J-06 (04-11-13) ~ ~.7~-26 (21-7-11-13) ~__~_~ W-35 (12-21-11-12) DESCRIPTION GR/CCL FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 5830.03 6031.05 6245.05 6251.03 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and return, Petrotechntcal Data Cente~ BP Exploration (Alaska) 900 East Benson Boulevard Da~e 'Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 10 June 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL c-os (41-25-1~-13) B-31 (44-31-11-14) ~3-~Y-36 (4~-27-11-~3) DESCRIPTION PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF GR/CCL FINAL BL+RF PLS FINAL BL+RF PLS FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 1680.04 5809.07 5830.02 6054.04 6181.05 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563'-7803 Received by: Date: Please sign and ~etu~,~ ~o~ Pe~rotechnical Da~a Centex- BP Exploration (Alaska) aE St Benson Boulevard e, Alaska 99508 -...JUN 1 6 199~ Alaska Oil & Gas Cons. Corrlm[ss.[qr~ Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 21 March 1995 RE: Transmittal of Data Sent by: ANCH.EXPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL x-0 B-02 (32-11-14) ~ (.~'i~,.B-31 (44-31-11-14) DESCRIPTION GR/CCL FINAL BL+RF GR/CCL FINAL BL+RF GR/CCL FINAL BL + RF PFC/PERF FNL BL+RF PLS FINAL BL+RF GR/CCL FINAL BL+RF · Run Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 3982.03 5787.09 5801.07 5803.11 5830.01' 6245.02 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by:, Date: Please s i~.D% and r.~urn ~bo,' Petrotechnioa! Data Cente? BP Explo?,~~tion (Alaska) 900 Ea:'-,:t ,Z*',~.?..~:~on Boulevard ~~rage~ ~.iaaXa 99508 .. ~as~ Oil & Gas Cons. Anchorage ~ . ~ { STATE OF ALASKA ~ ' ALA.,_,,,,:A OIL AND GAS CONSERVATION COMMIS$. . k.././."... REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate _ Plugging~ Perforate X. Pull tubing Alter casing. Repair well Other_Y,_ 2. Name of Operator 6. Datum elevation (DF or KB) ' ~,,/" BP Exploration (Alaska) Inc. KBE=67. 70 feet 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2105' SNL, 1609' WEL, SEC. 31, T11N, R14E At top of productive interval 4169' SNL, 1369' WEL, SEC. 31, T11N, R14E At effective depth 4454' SNL, 1472' WEL, SEC .31, T11N, R14E At total depth 4428' SNL, 1455'WEL, SEC. 31, T11N, R14E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2654 Intermediate 9147 Production -- Liner 8906 Perforation depth: 5. Type of Well: Development ~ Exploratory Stratigraphic 7. Unit or Property name Service X Prudhoe Bay Unit 8. Well number B-3 li(44-31-11-14) 9. Permit number/approval number 91-46 /90-080 10. APl number 50- 029-22152 11. Field/Pool Prudhoe Oil Pool 9840' feet Plugs (measured) 9228' feet 9897' feet Junk (measured) 9191' feet Size Cemented Measured depth 20 138 13-3/8 3723 C. F. Arcticset Ill&Il 2682 9-5/8 1866 C. F. C/ass G 9175 True vertical depth BKB 138 2682 865O 7 280 C. F. Class G measured 9370'-9384', 9398'-9454',9460'-9490' 8906-9840 8421-9227 true vertical subsea Tubing (size, grade, and measured depth) 7"26# L-80, NSCC to 9175' Packers and SSSV (type and measured depth) 13.3/8"X9-5/8~'Packer @ 8805', SSSV @ 2102 13. Stimulation or cement squeeze summary See Attachment Alaska Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure N/A N/A N/A N/A 24276 Tubing Pressure N/A 1935 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Water Injector 17. I hereby certify that the foregoing~is true and correct to the best of my knowledge. Signed f~' ,ACA/t ~,v~ (L //.~~ Title Senior TechnicalAssistantl Form 10-40~ R~e~ 06/15/88 /' ' ' Date ?'/~ I,/¢? SUBMIT IN DUI6LIC~'TE 5/30/92 5/31/92 WELL B-31i(44-31-11-14) Injection C0nversion/AddPerf #92-080 The well was converted from producer to water injection. The following interval were added perforation using 3 3/8" guns, 4 SPF, random orientation and 120° phasing. 9290' - 9370' MD fjh 3/13/93 BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 56%5111 DATE: 01-07-93 T# 84260 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 12/28/92 REFill4983 12/30/92 REF#124604 12/31/92 REF#114986 12/31/92 REF#124605 12/29/92 REF#124603 12/29/92 REF#114984 PRODUCTION LOGGING INJE ATLAS COLLAR LOG (PERFORATING ATLAS PRODUCTION LOGGING INJE ATLAS PFC GAMMA RAY; PERFORAT ATLAS PFC GAMMA RAY; PERFORAT ATLAS CASING COLLAR LOCATOR(T ATLAS Information Services Well Records CEIVED JAN 2. 5 1995 /'Jaska Oil & Gas Cons. Commission Anchorage " 0 R I A t A{ ,<A OILAND GAS CONSERYATION ,lq REPORTOF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2105' SNL, 1609' WEL, SEC.31, T11N, R14E At top of productive interval 4169' SNL, 1369' WEL, SEC.31, T11N, R14E At effective depth 4454' SNL, 1472' WEL, SEC .31, T11N, R14E At total depth 4428' SNL, 1455'WEL, SEC. 31, T11N, R14E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE=67. 70 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-31(44-31-11-14) 9. Permit number/approval number 91-46/ 10. APl number 50- 029-22152 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2654 Intermediate 9147 Production -- Liner 8906 Perforation depth: measured 9840'feet Plugs (measured) 9228'feet 9897'feet Junk (measured) 9191~eet Size Cemented 20 13-3/8 3723 C. F. Arcticset Ill&Il 9-5/8 1866 C. F. Class G 7 280 C. F. Class G 9370'-9384 ', 9398'-9454 ', 9460 '-9490' true vertical subsea8752'-8764',8776'-8825',8830'-8856 Measured depth True vertical depth BKB 138 138 2682 2682 9175 865O 8906-9840 8421-9227 RECEIVED Tubing (size, grade, and measured depth) 7"26#L-80, NSOCto 9175' SEP - 8 199'2 Alaska .0il & Gas Cons,, Packers and SSSV (type and measured depth) 13-3/8"X 9-5/8" Packer @ 8805', SSSV@ 2102 ~.l~c[lorag~ "i3'. stimulati® or cement squeeze summary 6/28/91 The following intervals below was perforated using 3 3/8 gun diameter, 4SPF, orientation and 90° phasing. Intervals treated (measured) 9370'- 9384', 9398'- 9454', 9460'- 9490' Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure New Well Inlector (Pre-Production Period) 14700v/~'12043 318 0 Tubing Pressure 354 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil. X Gas Suspended 17. I hereby certify that the,,fo, rego~,is true and correct to the best of my knowledge. Signed '~,.~ ~_~ ~C"~vq, o,~ ! - Service Form 10-404 I~ev 06/15/88 / Title Senior Technical Assistant I Date r~'7/~ 3/¢'~ ] SUBMIT IN DEipLtdA'rE - BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/02/92 T# 83667 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 06/18/92 #1 06/20/92 #1 06/22/92 #1 06/18/92 #1 06/20/92 #1 06/18/92 #1 9200 00- 9753.00 CAMCO 5 " 3000 00-13404.00 CAMCO 2 " 9550 00- 9800.00 CAMCO 5 " 3050 00-11150.00 CAMCO 2/5" 9300 00- 9600.00 CAMCO 5 " 2900 00- 9100.00 CAMCO 2/5" Information Control Well Records Adrian J. Martin RECEiVED JUL '1 4 1992 Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 06/26/92 T# 83648 BP CASED HOLE FINALS Enclosed is your copy of the materials listed questions, please contact BP Well Records at B-29 ~ $'/~PERF B-31 ~i"~ PERF F-14 ~6;--[~' PERF D-O87~.~ PERF 05/29/92 #1 05/31/92 #1 05/20/92 #1 06/02/92 #1 below. If you have any (907) 564-4004. 8400.00- 9410.00 HLS 5 " 8700.00- 9600.00 HLS 5 " 9995.00-10350.00 HLS 5 " 8650.00-10330.00 HLS 5 " Information Control Well Records Adrian J. Martin ,/ RECEIVED JUL 1 4 1992 Alaska Oil & Gas Cons. Commission Anchorage 1. Type of Request: l'II' STATE OF ALASKA ' ~{. -';KA OIL AND GAS CONSERVATION COMM[..)N APPLICATION FOR SUNDRY APPROVALS Abandon ~ Suspend __ Operation Shutdown ~ Re-enter suspended well ~ Alter casing Repair well Plugging ~ Time extension ~ Stimulate ~ Change approved program ~ Pull tubing Variance__ Perforate ~ Other 5. Type of Well: Development__ Exploratory __ Stratigraphic __ Service X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2105' SNL, 1609' WEL, SEC.31, T11N, R14E At top of productive interval 4169' SNL, 1369' WEL, SEC.31, T11N, R14E At effective depth 4454' SNL, 1472' WEL, SEC .31, T11N, R14E At total depth 4428'SNL, 1455'WEL, SEC. 31, T11N, R14E 12. Present well condition summary Total depth: measured true vertical 6. Datum elevation (DF or KB) KBE=67.70 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-31(44-31-11-14) 9. Permit number 91-46 10. APl number 50- 029-22152 11. Field/Pool Prudhoe Oil Pool 9840' feet Plugs (measured) 9228' feet Measured depth True vertical depth BKB 138 138 2682 2682 9175 8650 8906-9840 8421-9227 Effective depth: measured 9897' feet Junk (measured) true vertical 9191' feet Casing Length Size Cemented Structural -- Conductor 110 20 Surface 2654 13-3/8 3723 C. F. Intermediate 9147 9-5/8 1866 C. F. Class Production -- Liner 8906 7 280 C. F. Class G Perforation depth: measured 9370'-9384', 9398'-9454',9460'-9490' true vertical subsea RECEIVED APR - 6 199 Alaska 0il & Gas Cons. CommjssJe Anchorage Tubing (size, grade, and measured depth) 7"26#L-80, NSCC to 9175' Packers and SSSV (type and measured depth) 13-3/8" X 9-5/8" Packer @ 8805; SSSV @ 2102 13. Attachments Description summary of proposal ~ Date approved Detailed operations program BOP sketch 15. Status of well classification as: Oil ~ Gas ~ Suspended ~ Service Convert well to Water Injector 14. Estimated date for commencing operation Estimated date of conversion is 4/15/92 16. If proposal was verbally approved Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned Title . ...q~/-~.,~,,,r., top- ~/Ak~sc.;j~\~, ~-l~,~.~. Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test .~ Location clearance ~ Mechanical Integrity Test _~ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED B~ LONP,II~. C, SHtTH Date ~-'~' c)~ , SUBMIT IN TRIPLICATE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, A.b~ka 99519-6612 (907) 561-5111 DATE: 01/16/92 T# 83187 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. -16 LEAK DET PROD-F 0~5 ~-I~ GAS LIFT SURVEY /~25 ~~'1°; TEMP ' ~,,-s-17~ ~1"#'/, G~S ~ SO~V~ - 2 4 ~EWE LRY 12/29/91 #1 12/26/91 #1 12/28/91 #1 12/26/91 #1 12/26/91 #1 12/30/91 #1 12/28/91 #1 12/25/91 #1 12/29/91 #1 12/30/91 #1 9800.00-11774.00 CAMCO 5 " 7580.00-10455.00 CAMCO 2 " 8500.00- 9462.00 CAMCO 5 " 2000.00-10229.00 CAMCO 2 " 350.00- 9467.00 CAMCO 2 " 8500.00-10200.00 CAMCO 2/5" 8500.00- 9462.00 CAMCO 5 " 2000.00- 9984.00 CAMCO 2 " 8700.00- 9740.00 CAMCO 5 " 8500.00-10200.00 CAMCO 12/28/91 #1 8500.00- 9462.00 CAMCO Information Control Well Records Adrian J. Martin RECEIVED JAN 2 2 1992 Alaska 011 & Sas Cons. Commission Anchorage - ^,^s,^ I'.' 0 I11 $ 1111 ii I. ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE I~ Water Injector 2. Name of Operator 7. Permit Number BP Exploration 91-46 3. Address B. APl Number Po 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22152 4. Location of well at surface 9. Unit or Lease Name 2105' SNL, 1609' WEL, SEC. 31, T11N, R14E ~ ~t;!?~.~?~o,~i~ '[' ' ~-- Prudhoe Bay Unit At Top Producing Interval jf~_,.,.TE ~_ ! ILOC''ATION~i 10. Well Number i ,~~_~jI ! VE~FIED B-31 (44-31-11-14) 4169'At TotalSNL'Depth1369' WEL, SEC. 31, T11N, R14E~ :~.~ED ~ 'Subj,. ~;' u~., 11. Field and Pool ~ ~...:_~ H'~..,~.z.z~. Prudhoe Bay Field/Prudhoe Bay Pool 4428' SNL, 1455' WEL, SEC. 31, T11N, R14E '-'--'-"-----' 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 67.70' I ADL 28310 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 04-23-91 05-09-91 06-28-91I N/Aeet MSL I ONE 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set ~1. Thickness of Permafrost 9840'M D/9228'TVD 9897'MD/9191'TVD YES [3~ NO []I 2102feet MD ! 2070' I 22. Type Electric or Other Logs Run BHCS/CNL/DIL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20' Surface 11 O' 13-3/8' 68# L-80 Surface 2682' 17-1/2" 3723 cuft Arcticset III & II 9-5/8' 47# L-80 Surface 9175' 12-1/4" 1866 cu ft Class G 7' 26# L-80 8906' 9840' 8-1/2" 280 cuft Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Western Atlas 3-3/8" @ 4 spf 7" 26# L-80 8906' 8805' MD TVDss 26. ACID, FRACTURE, CEMENT SQUEF_Z~, ETC. 9370'-9384' 8752'-8764' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED 9398'-9454' 8776'-8825' 13-3/8" x 9-5/8" Freeze Protect Annulus w/150 9460'-9490' 8830'-8856' bbls Dry Crude 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) July 7, 1991 I Injecting Water Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF iNATER-BBL CHOKE SIZE IGAS-OIL RATIO rEST PERIOD I~ I Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF ~NATER-BBL DIL GRAVITY-APl (corr) ' Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. R£C£1V£D S EP 1 9 Alaska 0il & Gas Cons. C0m~tsstetl- 'Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,., , , ' GEOLOGIC MARKEFI~ , ORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag 9170' 864 7' Shub/ik A 9200' 8673' Zone 4 9291' 8751' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Sign~d~'~~-.~ L...,~/( ~ ~ Title Senior Technical Assistant Date '~//~//~// / / / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply ,for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 · If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday. April 24. 1991 WELL: B-31 (44-31-11-14~ APl No. 50-029-221 52 Day: 1 Depth at 0600 Hrs. = 600 Ft. 24 Hour Footage = 490 Ft. Reason for Overexpenditure: Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Rig #18-E 125399 (~urrent Operation: , Drilling at 600' Summary of Last 24 Hours: Accepted rig at 12.00hrs 4/23/91. Spudded at 18.00hrs 4/23/91. Drilled 17-1/2" hole to 600' Mud Type Mud Weight Viscosity P V YP Fluid Loss Solids Temp Spud Mud 9.0 Cf/gal 155 Sec. 27 43 18.0 cc 5%. ,"',' °F Depth Angle Direction TVD N,S E-W Dog Leg Section (~0ordinate Co0rclinate °/100' RECEIVED S E P ~ 9 · Aiasl(a Oil & Gas Cons. Commission Anchorage Reviewed By: MJS BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: As of 0600 Hrs. Friday. Aoril 26. 1991 WELL: B-31 (44-31-11-14) PRUDHOE BAY UNIT APl No. 50-029-221 52 Day: .,3. Depth at 0600 Hrs. = 2,705 Ft. 24 Hour Footage = 930 Ft. Reason for Overexpenditure: Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Riq #18-E 125399 Current Operation: Running 13-3/8" casing. Summary of Last 24 Hours: Drilled to 2332'. Tripped for bit change. Ddlled to 2705'. POH. Ran 13-3/8" casing Mud Type Mud Weight Viscosity ....P. V YP, Fluid Loss Solids Spud Mud 9.7 #/gal 145 Sec. 27 44 16.0 cc 1 0% -I-emp Survey DeDth Angle Direction ,TV~) N-S E-W Section Coordinate Coordinate · Do'g Leg o/100' Reviewed By: MJS BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Monde, y, April 29. 1991 WELL: B-31 (44-31-11-14) AP! No. 50-029-22152 Day: 6 Depth at 0600 Hrs. = 4,500 Ft. 72 Hour Footage = 1,795 Ft. Reason for Overexpenditure: Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Riq #18-E 125399 Current Operation: Tripping for kick-off assy. Summary of Last 72 Hours: Ran and cemented 13-3/8" csg. Performed top job. Replaced bearings on rotary drive shaft. Drilled out casing, drilled to 4500'. POH MudType Mud Weight Viscosity P V YP Fluid Loss Solids. "T~mp Low solids 9.2 #~gal 35 Sec. 5 1 5 18.0 cc 6% 67 °F N-$ E-W Dog Leg Survey Depth Angle Direction TVD Section Coordinate Coordinate °/100' Reviewed By: MJS BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Tuesday. April 30. 1991 WELL: B-31 (44-31-11-14~ APl No. 50-029-22152 Day' Z Depth at 0600 Hrs. = 5,160 Ft. 24 Hour Footage = 660 Ft. Reason for Overexpenditure: Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Riq #18-E 125399 Current Operation' Tripping for assy. change Summary of Last 24 Hours' Tripped for mud motor assy. Drilled to 5160'. POH Mud Type Mud Weight Viscosity Low solids 9.2 #/gal 37 Sec. P V .Yp Fluid Loss Solids ..Temp 6 8 10.0 cc 6% 70 °F Survey Depth Angle Direction N-S E-W DogLeg TVD Section Coordinate Coordinate °/100, Reviewed By' MJS BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: ,PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday. May 1. 1991 - _ WELL: B-31 (44-31-11-14) APl No. 50-029-22152 Day: 8 Depth at 0600 Hrs. -- 6,130 Ft. 24 Hour Footage = 970 Ft. Reason for Overexpenditure: Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Rig #18-E 125399 Current Ooeratign: Drilling at 6130' Summary of Last_ 24 Hours' Tripped for assy. change. Drilled to 5649'. Tripped for assy. change. Drilled to 6130' Mud T_vpe Mud Weight Viscosity P,V .YP Fluid Loss Solids Low solids 9.4 #/gal 36 Sec. 6 8 8.0 cc 8% TemD - 82OF Survey Depth Angle Direction TVD N'S E-W Section Coordinate Coordinate Dog Leg °/100' Reviewed By: ,MJS BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: As of 0600 Hrs. Thursday. May 2. 1991 WELL: B-31 (44-31-11-14) PRUDHOE BAY UNIT APl No. 50-029-221 52 Day: ~ Depth at 0600 Hrs. = 6.613 Ft. 24 Hour Footage = 483 Ft. Reason for Overexpenditure: Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Rig #18-E 125399 Current Operation; Tripping for bit and BHA change. Summary of Last 24 Hours' Drilled to 6476'. Tripped to P/U mud motor. Drilled to 6613'. Tripped for bit and BHA change. M~dType Mud Weight Viscosity P V YP Fluid Loss Solids Low solids 9.5 #/gal 38 Sec. 8 1 1 8.0 cc 9% Temp ,",¢2 OF N-S, E-W Survey Depth Anale ,DirectiQn TVD. Section Coordinate Coordinate .Dog Leg °/100' Reviewed By' MJS BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: As of 0600 Hrs. Frid~ty. May 3. 1991 WELL: B-31 (44-31-11-14) PRI. JDHOE BAY UNIT APl No. 50-029-22152 Day: 9 Depth at 0600 Hrs. = 7,444 Ft. 24 Hour Footage -- 831 Ft. Reason for Overexpenditure: Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Riq Cf18-E 125399 Current Operation' POH - plugged jets Summa~ of Last 24 Hours' RIH. Drilled to 7444'. Tripped for bit change. POH to unblock jets. Mud Type Mud Weight Viscosity p V Low solids 9.7 Cf/gal 45 Sec. 1 2 ,Yp Fluid Loss Solids ,T.emp 11 6.4 cc 10%' ' 88 °F Survey, Depth Angle Direction TVD N-S E-W Section Coordinate Coordinate Dog .Leg 0/100' Reviewed By: MJS BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: As of 0600 Hrs. Monday. May 6. 1991 WELL: B-31 (44-31-11-14) PRUDHOE BAY UNIT APl No. 50-029-2215'2 Day: 1 2 Depth at 0600 Hrs. = 9,183 Ft. 72 Hour Footage = 1,739 Ft. Reason for Overexpenditure: Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Rig #18-E 125399 Current Operation: POH Summary of Last 72 Hours: Drilled to 9183'. P©H. Mud Type Low solids Mud Weight 9.7 #/gal Viscosity 38 Sec. PV YP Fluid LOss Solids Temp 8 7 5.6 cc 11%. "9I °F Survey Depth Anale Directigr~ TVD N-S E-W Dog Leg SectiQn Coordinate Coordinate °/100' Reviewed By: MJS BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: As of 0600 Hrs. Tuesday, May 7. 1991 WELL: B-31 (44-31-11-14) PRUDHOE BAY UNIT APl No. 50-029-22152 Day: 1--3 Depth at 0600 Hrs. = 9,183 Ft. 24 Hour Footage = Ft. Reason for Overexpenditure' Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Riq #18-E 125399 Current Operation' Testing BOPs Summary of Last, 24 Hours: POH. Ran and cemented 9-5/8" casing at 9175'. Installed and tested pack-off. MudType Mud Weight Viscosity P V YP. Fluid Loss Solids Temp Low solids 9.8#/gal 42Sec. 9 8 5.8cc 1 1% ,".',82°F Survey Depth Angle Direction TVD N-S E-W Dog Leg Sectiort Coordinate Coordinate °/100' Reviewed By: MJS BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday. May 8. 1991 WELL: B-31 (44-31-11-14) AP! No. 50-029-22152 Day: 1 4 Depth at 0600 Hrs. = 9,183 Ft. 24 Hour Footage = Ft. Reason for Overexpenditure: Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Rig #18-E 125399 Current Ooeration: Circ. and cond. mud Summary of Last 24 Hours: Tested BOPs. RIH with new BHA. Drilled cmt and cond. cont. mud 8639'-9174'. Tested casing to 3,000psi. Circ. and cond. mud MudType Mud Weight Viscosity P V YP Fluid Loss Solids' '",T'emp Non-dispersed ' 8.6 Cf/gal 38 Sec. 5 1 5 20.0 cc 2% 68 °F Survey Depth Angle Direction N-$ E-W Dog Leg TVD Section Coordinate Coordinate °/100' Reviewed By: MJS BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: As of 0600 Hrs. Thursday. May 9. 1991 WELL: B-3I (44-31-11-14) PRUDHOE BAY UNIT APl No. 5O-O29-22152 Day: 15 Depth at 0600 Hrs. = 9,796 Ft. 24 Hour Footage = 613 Ft. Reason for Overexpenditure: Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Rig #18-E 125399 Current Operation: Drilling 8-1/2" hole. Summary of Last 24 Hours: Conditioned mud. Drilled 8-1/2" hole to 9796'. Mud Type Mud Weiqht. Viscosity Dispersed 8.5 #/gal 36 Sec. PV YP. Fluid Loss Solids. ,".Temp 5 7 11.0cc 120% 84 °F Survey Depth Angle Direction N-S. E-W DOg Leg TVD Section Coordinate Coordinate °/100' Reviewed By: RIS BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: As of 0600 Hrs. Friday. May 10. 1991 WELL: B-31 (44-31-1t-14) PRUDHOE BAY UNIT APl No. 50-029-22152 Day: .1 6 Depth at 0600 Hrs. = 91840 Ft. 24 Hour Footage = 44 Ft. Reason for Overexpenditure: Rig' AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Riq #1 8-E 125399 Current Operation: Run 7" liner. .St~.mmary of Last 24 Hours: Drilled to 9840'. Ran logs. RU and run 7" liner. Mud Type Mud Weight Viscosity Dispersed 8.5 #/gal 39 Sec. p,V YP Fluid LOSS Solids Temp 5 4 9.0cc 2% ,",78°F Survey Depth Angle Directi<;;)n TVD N-S E-W Dog Leg Section Coordinc~te Coordinate °/100' Reviewed By' '('~' BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: As of 0600 Hrs. MQnclay, May 13, 1991 WELL: B-31 (44-31-11-14) PRUDHOE BAY UNIT APl No. 50-029-22152 Day: .1. 9 Depth at 0600 Hrs. = .9,840 Ft. 72 Hour Footage = Ft. Reason for Overexpenditure: Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Riq #18-E 125399 Current Ooeration' Circ. well to filtered seawater Summary of Last 72 Hours' Ran and cemented 7" liner at 9840'. Cleaned out 9-5/8" casing and 7" liner. Circ. to filtered seawater MudType Mud Weight Viscosity. P V YP. Fluid Loss Solids Seawater 8.5 #/gal Sec. cc .',Temp 0F Survey Depth Angle Direction TVD N-,.,q E-W Section Coordinate Coordinate Dog Leg 01100' Reviewed By' MJS BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: As of 0600 Hrs. Tuesday, May 14, 1991 WELL: B-31 (44-31-11-14) PRUDHOE BAY UNIT APl No. 50-029-22152 Day: 20 Depth at 0600 Hrs. = 9,840 Ft. 24 Hour Footage = Ft. Reason for Overexpenditure: Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Riq #18-E 125399 Current Ooeration: Running 7" tubing Summary of Last 24 Hours: Circ. well to filtered brine. Ran CBT/CET log. RIH, with polish mill. Polished liner top. POH laying down D/P. Ran 7" tubing MudType Mud Weight Viscosity P V YP Fluid Loss Solids ',Temo Brine 8.5#/gal Sec. cc °F Survey Depth Angle Direction N-$ E-W Dog Leg TVD Section Coordinate Coordinate °/100' Reviewed By: MJS BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday, May 15, 1991 WELL: B-31 (44-31-11-14) AP! No. 50-029-22152 Day: 21... Depth at 0600 Hrs. = 9,840 Ft. 24 Hour Footage = Ft. Reason for Overexpenditure: Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Rig #18-E 125399 Current Oper~tiQn: Freeze protecting tubing. Summary of Last 24 Hours' Ran and landed 7" completion. Freeze protected tubing and annulus with diesel Mud Type Mud Weight Viscosity p.V .YP. Fluid LQ$S Solids Brine 8.5#/gal Sec. cc Temp Survey Depth Angle Dire6tiQn TVD N-S E-W Section, Coor¢inate Coordinate Doo Leq °/100' Reviewed By: MJS BP EXPLORATION (ALASKA), .INC. DAILY DRILLING REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Thursday. May 16, 1991 WELL: B-31 (44-31-11-14) APl No. 50-029-22152 Day: 22 Depth at 0600 Hrs. = 9,840 Ft. 24 Hour Footage = Ft. Reason for Overexpenditure: Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = Nabors Rig Cf1 8-E 125399 Current Operation; Released rig. Summary of Last 24 Hours: Freeze protected tubing and annulus. Set packer, pressure tested annulus. Set BPV. Released rig at 13.00 hrs. on 5/15/91. · . MudType Mud Weight Viscosity P V ,YP, Fluid Loss Solids ',Temp Brine 8.5Cf/gal Sec. cc °F Survey DePth, Angle Direction N-$ E-W Dog Leg TVD. Section Coordinate Coordinate °/100' Reviewed By: MJ, S Teleco Oilfield ~r 6116 Nielson way Anchorage, AK 99518 (907) 562-2646 ices Inc. June 4, 1991 JOB #820 BP EXPLORATION (ALASKA) INC. WELL: B-31 PRUDHOE BAY ~ RIG: NABORS 18E %k' Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to BP Exploration (Alaska) Inc. Teleco is committed to providing the highest quality MWD SerVice and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Jonathan G Field Operations Supervisor JGM/el Enclosures 7%las~a 0ii & Gas Cor~s. 'Anchorage A S~NAT COMPANY q/,qb DIRECTIONAL SURVEY r~ UIDANCE ~'J ONTINUOUS ~ OOL RECEIVED Alaska Oil & Gas Cons. ~nchorage Company BP EXPLORATION Well Name B-31 (44-31-11-14)(2105'SNL,1609'WEL,SEC 3.1,T11N,R14E/ Field/Location PRUDHOE BAY~ NORTH SLOPEr ALASKA Job Reference No. Date 74683 27-JUN-1991 Loclqed By: Computed By: G. JOttNSON S. DEES GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR BP EXPLORATION B-31 (44-31-11-14) PRUDHOE BAY NORTh SLOPE. ALASKA SURVEY DATE: 27-JUN-199~ METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: ENGINEER: G. JOHNSON TANGENTIAL- Averaged deviation and azimuth LINEAR HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 4 DEG 12 MIN EAST COMPUTATION DATE: 12-JUL-91 PAGE 1 BP EXPLORATION B-31 (44-31-11-14) PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 27-JUN-1991 KELLY BUSHING ELEVATION: 67.70 FT ENGINEER: G, JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTh TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MiN DEG MIN VERTICAL DOGLEG RECTANGULAP COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ FEET DEG/IO0 FEET FEET FEET DEG MI~ 0 O0 100 O0 200 O0 300 O0 4O0 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0.00 100,00 200.00 300.00 400.0O 499.99 599.99 699.99 799.99 899.99 -67 70 32 30 0 4 132 30' 0 20 232 30 0 16 332 3O 0 21 432 29 O 19 532 29 0 18 632 29 0 17 732.29 0 1i 832.29 0 2 0 0 N 0 0 E S 60 21 E S 49 39 E S 15 41 E S 25 13 E S 13 23 E S 14 26 E S 2 18 E S 3 15 W S 2 43 W 0.00' 0.00 0.32 O.73 ! .29 1 .81 2.4~ 2.87 3.34 3.62 0.00 0.40 0.13 0 O0 0 O0 0 O0 0 O0 03! 0 18 0 26 0.00 N 0.00 N 0.30 S 0.69 S 1.23 S 1.75 S 2.34 S 2.79 S 3.27 S 3.55 S 0 O0 E 00! E 031 E 0 57 E 0 79 E 0 94 E 10 E 15-2 i 17 E 1 !z~ E 0.00 N 0 0 E 0.01 N 78 57 E 0.43 S 46 14 E 0.89 S 39 30 E ! .46 S 32 35 E ;.99 S 28 18 E 2.58 S 25 15 E 3.02 S 22 2/. E 3.47 S 19 44 E 3.73 S 17 54 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 !900 999.99 932.29 0 0 O0 1099.99 1032.29 0 3 O0 1199.99 1132.29 0 7 O0 1299.99 1232.29 0 10 O0 1399.99 1332.29 0 8 O0 1499.99 1432.29 0 11 O0 1599.99 1532.29 0 6 O0 1699.99 1632.29 0 8 O0 1799.99 1732.29 0 8 O0 1899.99 1832.29 0 16 S 2 14 W S 40 22 W N 51 OW N 55 10 W N 34 18 W N 33 1 W N 84 18 W S 38 45 W S 10 13 E S 33 6 E 371 3 75 3 72 3 52 3 33 3 10 2 92 2 99 3 18 3 53 0.00 0.00 0.10 0.00 0.00 0.00 0.00 0.00 0.00 0.32 3.64 S 3.69 S 3.66 S 3.48 S 3.30 S 3.08 S 2.91 S 3.00 S 3.19 S 3.53 S i 12 E I 05 E 0 97 E 071 E 0 53 E 0 39 E 0 19 E 0 03 E 0 02 W 0 1i E 3.80 S 17 7 E 3.83 S 15 54 E 3.78 S 14 49 E 3.55 S 11 30 E 3.34 S 9 5 E 3, 10 S 7 10 E 2.92 S 3 43 E 3.0O S 0 35 E 3. 19 S 0 19 W 3.53 S 1 43 E 2000 O0 1999 99 1932 29 0 27 2100 2200 230O 2400 2500 2600 2700 2800 2900 O0 2099 O0 2199 O0 2299 O0 2399 O0 2499 O0 2599 O0 2699 O0 2799 O0 2899 98 2032 98 2~32 97 2232 96 2332 95 2a32 94 2532 94 2632 93 2732 93 2832 28 0 27 28 0 40 27 0 44 26 0 48 25 0 45 2/. 0 42 24 0 35 23 0 30 23 0 29 S 71 41 E S 71 32 E S 78 10 E S 73 59 E S 68 22 E S 58 54 E S 43 2~, E S 26 9 E S 13 52 E S 11 32 E 3 92 4 19 4 50 4 85 541 6 10 6 9O 781 8 78 9 59 0.23 0 21 013 0 62 0 O0 0 40 0 16 0 05 0 24 0 10 3.89 S 4 11 S 4 34 S 4 61 S 5 08 S 5 67 S 641 S 7 27 S 8 22 S 9 03 S 0 64 E '.' 33 E 2 33 E 3 44 E 48' E 6 02 E 6 96 F_ 7 62 E 7 95 E 8 08 E 9,4 S 9 21 E 32 S 17 58 E 93 S 28 12 E 75 S 36 43 E 99 S 43 28 E 27 S 46 43 E 46 S 47 2C E 53 S 46 20 E 44 S 44 o ~ 12.11 S 41 50 E 3000.00 2999 93 2932 23 3!00 O0 3099 32OO O0 3!99 3300 O0 3299 34OO O0 3399 3500 O0 3499 3600 O0 3599 37O0 O0 3699 3800 O0 3799 3900 93 3032 92 3i32 92 3232 92 3332 92 3432 92 3532 92 3632 92 3732 O0 3899.92 3832 23 22 22 22 22 22 22 22 22 0 25 0 22 0 22 0 22 0 17 0 16 02i 0 17 0 17 0 16 S 2 23 E S I 15 E S 7 35 E S 0 34 W S 5 15 W S 9 23 W S 13 32 W S 16 57 W S 25 26 W S 24 57 W 10 32 10 96 11 56 12 11 12 64 13 15 13 66 14 15 14 59 15 O3 0.00 0.29 0.31 0.42 0.00 0.00 0.00 0.00 0.14 0.00 9 75 S 10 39 S i0 99 S 11 54 S 12 07 S 12 58 S 13 10 S 13 60 S 14 06 S 14 52 S 8 17 E 8 20 E 8 20 E 8 2~ E 821 E 8 17 E 8 03 E 791 E 7 72 E 7 56 E 12 72 S 39 57 E 13 13 1,4 14 15 15 15 16 16 23 S 38 18 E 71 S 36 45 E 16 S 35 26 E 60 S 34 14 E O0 S 33 0 E 37 S 31 31 E 74 S 30 11 E 04 S 28 47 E 37 S 27 30 E COMPUTATION DATE: 12-JUL-91 PAGE 2 BP EXPLORATION B-31 (44-31-11-14) PRUDHOE BAY NORTH SLOPE, ALASKA DATE Of SURVEY: 27-JUN-1991 KELLY BUSHING ELEVATION: 67.70 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ FEET DEG/IO0 FEET FEET FEET DEG MiN 4000 O0 3999.92 3932 22 4100 4200 4300 4400 4500 4600 4700 4800 4900.00 4897 O0 4099 92 4O32 O0 4199 O0 4299 O0 4399 O0 4499 O0 4599 O0 4699 O0 4798 92 4132 92 4232 92 4332 92 4432 88 4532 63 4631 93 4731 65 4829 0 17 5 12 36 W 22 0 20 S 15 42 W 22 0 14 S 23 30 W 22 0 7 5 43 46 W 22 0 7 S 54 58 W 22 0 11 S 33 7 W 18 2 38 S 16 18 E 93 5 28 S 15 22 E 23 8 0 S 16 4 E 95 10 6 S 15 5 E 16 19 25 37 52 15 5O 15 92 16 37 16 6,4 16 82 91 02 84 3,4 98 0.30 0.10 0.00 0 26 0 09 0 78 2 36 3 2O 2 88 I 99 15 O0 S 15 ,43 S 15 90 S 16 17 S 16 37 S 16 48 S 18 ,56 S 25 25 S 36 54 S 51 93 S 7 37 E 7 22 E 7 08 E 6 98 E 6 79 E 6 56 E 7 04 E B 91 E 12 19 E 16 19 E 16 72 S 26 9 E 17 17 17 17 17 19 26 38 54 04 S 25 3 E 40 S 24 0 E 62 S 23 20 E 72 S 22 32 E 74 S 21 43 E 85 S 20 46 E 78 S 19 26 E 52 S 18 27 E 40 S ;7 19 E 5000 O0 4995 64 4927.94 13 3 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 5092 O0 5187 O0 5282 O0 5374 O0 5465 O0 5554 O0 5641 O0 5728 O0 5815 40 5024.70 16 8 89 5120.19 18 19 15 5214.45 20 41 84 5307.14 23 21 72 5398.02 25 55 57 5486.87 28 39 75 5574.05 29 47 52 5660.82 29 48 40 5747.70 29 45 S 15 52 E 72.45 S 15 18 E 97.-17 S 16 5 E 126.26 S 17 34 E 158.85 S 19 27 E 195.16 S 20 0 E 235.31 S 20 32 E 279.41 S 20 51 E 326.36 S 21 1 E 373.97 S 2O 57 E 42!.37 3.40 2.55 2.44 2 70 2 67 2 60 2 12 0 54 0 44 0 84 71.06 S 95.36 S 28 123.93 S 36 155.9] S 45 191.43 S 57 230.65 S 71 273.71 S 87 319.51 S 105 365.95 S 122 412.17 S 140 21 60 E 74.27 S 16 55 E 30 E 99.47 S 16 32 E 28 E 129.13 S 16 19 E 87 E 162.52 S 16 24 E 85 E 199.98 S 16 49 E 99 E 241.63 S 17 20 E 85 E 287.46 S 17 48 E 17 E 336.38 $ 18 13 E 92 E 386.04 S 18 34 E 65 E 435.51 5 18 51 E 6000 O0 5902.02 5834 32 30 8 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 5988.43 5920 O0 6074.88 6007 O0 6161.48 6093 O0 6248.04 6180 O0 633~.58 6266 O0 642i.25 6353 O0 6507.48 6439 O0 6593.4! 6525 O0 6679.56 66i~ 73 30 20 18 29 56 78 3O 0 34 30 1 88 30 2 55 30 3 78 30 43 7! 30 42 86 30 ~8 S 20 43 E S 20 53 E S 21 0 E S 20 48 E S 20 35 E S 17 54 E S 11 33 E s lO 21 E S 9 -44 E S 9 17 E 469 27 517 50 565 62 613 5! 661 53 709 80 758 86 809 16 860 05 9~0 60 0 47 0 O0 0 26 0 09 0 16 3 44 i 8! 0 46 0 53 0 45 458.90 s 158 39 E 485.47 S 19 3 E 505.95 S 176 552.88 S 194 599.58 S 212 646.44 S 229 693.60 S 246 741.87 S 259 79i.62 S 268 841.99 S 277 892.06 S 285 26 E 535 77 S 19 12 E 26 E 586 10 E 635 77 E 686 70 E 736 !3 E 785 57 E 835 51E 886 85 E 936 Ol S 19 22 E 99 S 19 29 E 06 S 19 34 E 17 S 19 35 E 82 S 19 15 E 94 S 18 44 E 54 S 18 1,4 ~ 74 S 17 ~6 E 7000 O0 6766 09 6698 39 29 53 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 6852 OO 6940 O0 7027 O0 7115 O0 7204 O0 7292 O0 7381 O0 7470 O0 7560 97 6785 ~a 6872 66 6959 70 7048 13 7136 65 7224 49 7313 83 7403 5O 7492 27 29 29 4~ 29 10 96 28 39 O0 27 58 43 27 53 95 27 36 79 27 1 13 26 25 8O 25 58 S 8 57 E S 8 35 E 1009 S 8 21 E 1058 S 8 6 E 1107 S 7 45 E 1t54 S 7 18 E 1200 S 6 6 E 1247 S 4 52 E 1293 S 3 36 E 1338 S 2 26 E 1382 960 55 9! 77 O3 35 97 44 34 27 52 0 44 0 27 0 45 0 75 0 92 0 61 0 56 0 73 0 36 0 97 941 56 S 293.79 E 986 33 S 17 20 E 990 50 S 301.31 E 1035 1038 97 S 308.53 E 1083 1086 85 S 315.43 E 1131 1133 82 S 321.96 E 1178 1180 11 S 328.08 E 1224 1226 31 S 333.50 E 1270 1272.01 S 337.90 E 1316 1316.82 S 341.18 E 1360 1361.02 S 343.54 E 1403 32 S 16 55 E 81 S 16 32 5 70 S 16 11 E 64 S 15 51 E 87 S 15 32 E 85 S 15 13 E 13 S 14 53 E 3O S 14 32 E 70 S 14 10 E BP EXPLORATION B-31 (44-31-11-14) PRUDHOE BAY NORTN SLOPE, ALASKA COMPUTATION DATE: 12-JUL-91 PAGE 3 DATE OF SURVEY: 27-JUN-1991 KELLY BUSHING ELEVATION: 67,70 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORiZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUT~ SECTION SEVERITY NORTH/SOUT~ EAST/WEST DIST. AZIMUTh DEPTH DEPTH DEPTH DEG MiN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 8000.00 7650 58 7582.88 25 40 S 1 21 E 1425.90 8100.00 7740 82OO.00 7827 83OO.0O 7913 8400.00 7996 8500.00 8078 8600.00 8i62 8700.00 8246 8800.00 833~ 8900.00 8416 15 7672.45 27 26 S 0 34 E 1470.28 80 7760 10 30 4 S 0 46 W 1518.26 13 7845 43 32 44 5 1 45 W 1570.15 19 7928 49 34 45 S 3 27 W 1625.45 62 8010 92 33 52 S 5 45 W 168i.39 17 8094 47 32 46 S 7 40 W 1735.35 72 8179 02 3i 55 S 9 50 W 1787.38 64 8263 94 31 53 S 11 41 W 1838.39 65 8348 95 31 46 S 13 44 W 1888.77 0 68 1404.40 S 344 95 E 1446 15 S 13 48 E 56 1448.85 S 345 55 1496.97 S 345 42 1549.09 S 344 68 1604.71 S 342 34 1661.13 S 337 57 1715.70 S 331 14 1768.47 S 323 01 1820.35 S 313 20 1871.71 S 30! 70 E 1489 62 E 1536 43 E 1586 05 E 1640 50 E 1695 17 E 1747 02 E 1797 14 E 1847 55 E 1895 52 S 13 25 E 35 S 13 0 E 92 S 12 32 E 76 S 12 2 E 07 S 11 29 E 37 S 10 55 E 73 S 10 2~ E 09 S 9 46 E 85 S 9 9 E 9000.00 8507 80 8434 10 31 26 S 15 55 W 1938.34 9100.00 8587 9200.00 8673 9300.00 8759 9400.00 8846 9500.00 8932 9600.00 9019 9700.00 9106 9800.00 9193 9840.00 9227 31 8519 20 8605 40 8691 05 8778 75 8865 53 8951 32 9038 04 9125 74 9160 61' 31 8 S 18 27 W 1986.61 50 30 40 S 19 41 W 2033 59 70 30 5 5 19 35 W 2079 96 35 29 55 5 19 8 W 2125 72 05 29 50 5 18 57 W 2171 50 83 29 45 5 18 9 W 2217 32 62 29 52 S 17 46 W 2263 36 34 29 50 S 17 37 W 2309 56 04 29 50 S 17 37 W 2328 03 1.39 1922.40 S 288 14 E 1943.87 S 8 31 E 1.33 1971.93 S 272 81 E 1990.71 S 7 53 E 0.28 2020.28 S 255 92 E 2036.42 S 7 13 E 0 59 2068.02 S 238 90 E 2087.77 S 6 35 E 0 20 2115.12 S 222 36 E 2126.77 S 6 0 E 0 33 2162.21S 206 11 E 2172.01 S 5 27 E 0 68 2209.32 S 190 27 E 2217.50 S 4 55 E 0 21 2256.60 S 175 05 E 2263.38 S ~ 26 E 0 O0 2304.03 S 159.93 E 2309.57 S 3 58 E 0 O0 2323.00 S 153.91 E 2328.09 S 3 47 E BP EXPLORATION 8-31 (44-31-11-14) PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 12-JUL-91 PAGE 4 DATE OF SURVEY: 27-JUN-1991 KELLY BUSHING ELEVATION: 67.70 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE .SUB-SE$ COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN ENGINEER: G. JOHNSON 0 O0 0 O0 -67 70 0 0 29 0 0 29 0 27 23 0 25 22 0 17 94 13 3 32 30 8 39 29 53 88 25 40 I0 31 26 99 932 99 1932 93 2932 92 3932 64 4927 02 5834 09 6698 58 7582 80 8434 1000 O0 999 2000 O0 1999 3000 O0 2999 40O0 O0 3999 5o0o O0 4995 6000 O0 5902 7000 O0 6766 8000 O0 7650 9000 oo 8501 VERTICAL DOGLEG RECTANGULAR COORDINATES HORiZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ FEET DEG/IO0 FEET FEET FEET DEG N 0 0 E 0.00 S 2 14 W 3.71 S 71 41 E 3.92 S 2 23 E 10.32 S 12 36 W 15,50 S 15 52 E 72.45 S 20 43 E 469,27 S 8 57 E 960.55 S 1 21 E 1425.90 S 15 55 W 1938.34 9840.00 9227.74 9160.04 29 50 S 17 37 W 2328.03 0 O0 0 O0 0 23 0 O0 0 3O 3 40 0 47 0 0 68 1 39 0 O0 N 3 64 S 1 3 89 S 0 9 75 S 8 15 O0 S 7 71 06 S 21 458.90 S 158 941.56 S 293 1404.40 S 344 1922.40 S 288 12 E 3 64 E 3 17 E 12 37 E 16 60 E 74 39 E 485 79 E 986 95 E 1446 14 E 1943 0 O0 E 0 O0 N 0 0 E 80 S 17 7 E 94 S 9 21 E 72 S 39 57 E 72 S 26 9 E 27 S 16 55 E 47 S 19 3 E 33 S !7 20 E 15 S 13 48 E 87 S 8 31 E 0.00 2323.00 S 153.91 E 2328,09 S 3 47 E COMPUTATION DATE: 12-JUL-9! PAGE 5 BP EXPLORATION B-31 (44-31-11-14) PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 27-JUN-1991 KELLY BUSHING ELEVATION: 67.70 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERT!m^'~..~_ DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUT~ EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 oo 67 70 167 70 267 70 367 70 467 70 567 7i 667 7! 767 71 867 7! 0 O0 67 7O 167 70 267 70 367 70 467 70 567 70 667 70 767 70 867 7O -67,70 0 0 N 0 0 E 0.00 0 1 N 53 3 E 100.00 0 19 S 44 33 E 200.00 0 15 S 24 17 E 300.00 0 23 S 25 41 E 400.00 0 18 S 12 22 E 500.00 0 22 S 15 7 E 600.00 0 15 S 3 13 E 700.00 0 15 S 3 3 E 800.00 0 9 S 0 28 W 0.00 0.00 0.20 0.58 1.10 1 ,64 2.23 c. 72 3.22 3.57 0 O0 0 OD 0 38 0 16 0 O0 0 O0 0 07 O 0 00 0 26 0.00 0.00 0.18 0.55 1.05 1.58 2.16 ~ 64 3.14 3.49 0 O0 E 0 O0 E 0 18 E 0 52 E 0 70 E 091 E I 05 E I !5 E 1 17 E I 14 E 0 O0 N 0 0 E O0 N 17 19 E 26 S 44 18 E 75 S 43 25 E 26 S 33 38 E 82 S 29 47 E 40 S 26 1 E 88 S 23 27 E 35 S 20 25 E 67 S 18 7 E 967 71 1067 1167 1267 1367 1467 1567 1667 1767 1867 967 70 71 1067 71 1167 71 1267 71 1367 71 1467 71 1567 71 1667 71 1767 71 1867 900.00 0 4 S 5 2 E 70 1000.00 0 4 S 50 33 W 70 1100.00 0 4 N 51 24 W 70 1200.00 0 12 N 55 33 W 70 1300.00 0 8 N 40 49 W 70 1400.00 0 10 N 32 19 W 70 1500.00 0 8 N 61 58 W 70 1600.00 0 7 S 52 23 W 70 1700.00 0 7 S 4 48 W 70 1800.00 0 15 S 23 28 E 3 69 3 73 3 76 3 59 3 40 3 18 2 94 2 95 3 ii 3 40 0.19 0.00 0.17 0.00 0.00 0.11 0.15 0.00 0.00 0.13 3.62 S 3.66 S 3.69 S 3.54 S 3.36 S 3.16 S 2.93 S 2.95 S 3.12 S 3.41 S 1.12 E 1.07 E 1 .01 E 0.80 E 0,58 E 0.44 E 0.25 E 0.08 E 0.02 W 0.04 E 3 79 S 17 9 E 82 S 16 21 E 83 S 15 15 E 63 S 12 41 E 41 S 9 42 E 19 S 7 55 E 94 S 4 54 E 95 S 1 36 E 12 S 0 25 W 41 S 0 38 E 1967.71 1967 70 1900.00 2067.72 2067 2167.72 2!67 2267.73 2267 2367,74 2367 2467.74 2467 2567.75 2567 2667,76 2667 2767.77 2767 2867.77 2867 70 2000 O0 70 2100 OD 70 2200 O0 70 2300 O0 70 2400 OO 70 2500 OO 7O 260O O0 70 2700 O0 70 2800.00 0 24 S 62 16 E 024 S 71 2 E 0 39 S 78 12 E 0 38 S 75 54 E 0 51 S 70 53 E 0 46 S 61 55 E 0 39 S 49 6 E 0 35 S 35 56 E 0 34 S 15 33 E 0 28 S 647 E 38! 4 10 4 40 4 73 5 22 5 85 6 6' 7 52 8 48 9 33 0 o7 0 17 0 oo 0 oo 0 15 0 30 0 54 0 25 0 08 001 3 79 S 4 03 S 4 27 S 451 S 49i S 5 45 S 6.14 S 6.99 S 7.93 S 8,76 S 0 42 E I 11 E I 96 E 3 08 E 4 37 E 5 64 E 6 68 E 7 45 E 7 ,87 E 8 04 E 3 8! S 6 18 E 4 4 5 6 7 9 10 11 11 18 S 15 24 E 70 S 24 42 E 46 S 34 17 E 58 S 41 41 E 85 S 45 58 E 07 S 47 26 E 22 S 46 49 E 17 S 44 48 E 89 S 42 32 E 2967 77 2967 70 2900 O0 3067 3167 3267 3367 3467 3567 3667 3767 3867 77 3067 78 3167 78 3267 78 3367 78 3467 78 3567 78 3667 78 3767 78 -3867 70 3000 70 3100 7O 320O 7O 3300 7O 3400 70 35O0 70 3600 70 3700 70 38OO O0 OO O0 O0 O0 O0 O0 O0 O0 0 24 S 4 16 E 021 S 7 25 E 0 20 S 2 50 W 0 18 S 4 2 W 0 17 S 1 23 ~" 0 17 S 4 12 W 0 19 S 17 35 W 0 16 S 15 21 W 017 ' S 25 4 W 0 16 S 18 32 w 10 10 10 76 11 36 11 92 12 48 13 O0 13 48 i4 O0 14 45 14 90 0.00 0.20 0.00 0 O0 0 O0 0 07 0 O0 0 O0 0 O0 0 O0 9 52 S 10 18 S 10 79 S 11 35 S I1 91 S 12 43 S 12 92 S 13 46 S 13 92 S 14 38 S 8 16 E 8 19 E 8 20 E 8 22 E 8 23 E 8 19 E 8 09 E 7 96 E 7 79 E 7 61 E 12 54 S 40 35 E 13 13 14 14 14 15 15 15 16 07 S 38 48 E 55 S 37 14 E 01 S 35 55 E 48 S 34 37 E 89 S 33 23 E 24 S 32 3 E 63 S 30 36 E 95 S 29 14 E 27 S 27 53 E BP EXPLORATION B-31 (44-31-11-14) PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 12-JUL-91 TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN PAGE 6 DATE OF SURVEY: 27-JUN-1991 KELLY BUSHING ELEVATION: 67.70 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTm EAST/WEST DIST. AZIMUTw, 3967 78 3967 70 3900 O0 0 20 S 16 31W O0 0 15 S 26 32 W O0 0 15 S 20 10 W O0 0 6 S 15 2 W O0 0 10 S 39 37 W O0 0 10 S 66 5O W O0 1 43 S 14 25 E 00 4 27 S 15 6 E O0 7 1i S 17 3 E O0 9 35 S 14 i2 E 4067 4!67 4267 4367 4467 4567 4667 4768 4869 FEET DEG/IO0 FEET FEET FEET DEG 70 4000 70 4100 70 4200 70 4300 70 4400 70 4500 70 4600 70 4700 70 4800 78 4067 78 4167 78 4267 78 4367 78 4467 79 4567 95 4667 49 4767 60 4867 4971.37 4967 70 4900 O0 12 5 5074.33 5067 70 5000 O0 15 23 5178.76 5167 70 5100 O0 17 52 5284.57 5267 70 5200 O0 20 18 5392.22 5367 70 5300 O0 23 9 5502.20 5467 70 5400 O0 25 58 5614.99 5567,70 5500.00 28 55 15 33 15 77 16 25 16 6O 16 77 16 86 17 8! 23 12 33 27 47 87 S 15 56 E 66.34 S 15 12 E' 90,32 S 15 51 E 119.80 S 17 14 E 153.58 S 19 21 E 192.17 S 20 0 E 236.24 S 20 37 E 286.34 0 35 001 0 O0 0 20 0 20 0 O0 3 38 2 74 2 26 ! 74 3 26 3 40 1 84 2 17 2 82 2 59 1 60 14 83 S 15 28 S 15 77 S 16 13 S 16 31 S 16 42 S 17 36 S 22 58 S 32 56 S 46 91 S 65.05 S 88.62 S 117.59 S 150.74 S 188.52 S 231.56 S 280.48 S 7 41 E 7 28 E 7 13 E 7 01 E 6 85 E 6 63 E 6 70 E 8 18 E !I O0 E 14 87 E 16 58 S 26 33 E 16 92 S 25 28 E 17 31 S 24 20 E 17 58 S 23 29 E 17 69 S 22 46 E 17 71 S 22 0 E 18 61 s 21 6 E 24 0! S 19 55 E 34 36 S 18 40 E 49 21 S 17 36 E 19 89 E 68.03 S 17 0 E 26 46 E 92.48 S 16 38 E 34 47 E 122,54 S 16 20 E 44 25 E 157.10 S 16 22 E 56 82 E 196.90 S 16 46 E 72 32 E 242.59 S 17 21 E 90 39 E 294.68 S 17 52 E 5729.91 5667 5845.12 5767 5960.33 5867 70 5600.00 29 53 70 5700.00 29 38 70 5800.00 30 . 3 S 20 53 E 340.62 S 21 0 E 395.38 S 20 44 E 450.19 6075 98 5967 70 5900.00 30 18 6191 6307 6422 6538 6653 6770 6886 7001 7116 72 6067 18 6167 71 6267 22 6367 78 6467 09 6567 26 6667 86 6767 92 6867 70 6000.00 29 57 70 6100.00 30 0 70 6200.00 30 3 70 6300.00 29 50 70 6400.00 30 28 70 6500.00 30 48 70 6600.00 30 2~ 70 6700.00 29 53 70 6800.00 29 27 S 20 5! E S 21 2 E S 20 46 E S 20 28 E S 15 8 E S 10 36 E S 9 58 E S. 9 19 E S 8 56 E 505.88 561.67 616.95 672.44 728,43 785.77 844.84 903.69 961.48 s 8 32 E 1018,2! 7231.54 6967 70 6900 O0 29 2 7345.56 7067 70 7000 7458,80 7167 70 7100 7571.84 7267 70 7200 7684.52 7367 70 7300 7796.51 7467 70 7400 7908.01 7567 70 7500 8019.01 7667 70 7600 8131.!5 7767 70 7700 8246.42 7867 70 7800 S 8 15 E I074.07 OO 28 20' S 7 56 E 1128.72 oo 27 47 O0 27 39 O0 27 6 O0 26 25 O0 25 55 O0 25 .49 O0 28 16 oo 31 21 s 7 30 E 1~81,76 S 6 26 E 1234,39 S 5 4 E 1286,30 S 3 38 E 1336,72 S 2 20 E 1386.02 S 1 12 E 1434.15 S 0 12 E 1484.79 S 1 17 W 1541,89 0 28 0 33 0 57 0 34 0 39 0 20 0 45 3 86 0 83 0 61 0 47 0 45 0 19 0 43 0 56 0 48 0 58 0 79 0 35 091 1 21 2.99 2.87 333.42 S 110 47 E 351,24 S 18 20 E 386.83 S 130 94 E 408.39 S 18 42 E 440.29 S 151 37 E 465.58 S 18 58 E 494.62 S 171 94 E 523 65 S 19 10 E 549.02 s 192 602.94 S 213 657.08 S 233 711.87 S 252 768.48 S 26; 826.93 S 274 885.22 $ 284 942.48 S 293 77 E 581 37 E 639 75 E 697 16 E 755 30 5 812 90 5 871 7~ E' 929 93 E 987 88 S 19 21 E 58 S 19 29 E 42 S 19 35 E 21 S 19 30 E 66 S !8 59 E 42 S 16 23 E 88 S 17 50 E 25 S ~7 i9 5 998.73 s 302 55 E 1043 56 S 16 5~ E 1054,15 S 310 74 E 1098 99 S 16 25 E 1108,37 S 315 1161,03 S 325 1213,33 S 332 1264,99 S 337 1315,27 S 341 1364,51 S 343 1412,66 S 345 1463,39 S 345 46 E 1153 21 S 16 2 E 60 E 1205 82 S !5 40 E 08 E 1257 95 S 15 18 E 29 E 1309 19 S 14 56 E 08 E 1358 77 S 14 32 E 68 E 1407 13 S 14 8 E 13 E 1454 21 S 13 44 E 80 E 1503 69 5 13 18 E 1520,69 S 345 18 E 1559,38 S 12 47 E COMPUTATION DATE: 12-JUL-91 PAGE 7 BP EXPLORATION B-31 (44-31-11-14) PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY; 27-JUN-1991 KELLY BUSHING ELEVATION: 67.70 FT ENGINEER: G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ~A_ DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTUR= TRUE SUB-SEA COURSE VERT!~ ~ ~ MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG M]N 8365 43 7967 70 7900.00 34 14 8486 83 8067 8606 56 8167 8724 71 8267 8842 44 8367 8960 O0 8467 9077.09 8567 9193.6; 8667 9309.59 8767 9424.98 8867 70 8000.00 34 3 70 8100.00 32 41 70 8200.00 31 52 70 8300.00 3! 45 70 8400.00 31 36 70 8500.00 31 12 70 8600.00 30 39 70 8700.00 30 70 8800.00 29 54 S 2 38 W 1606.03 S 5 29 W 1674.12 S 7 49 W 1738.81 S 10 20 W 1800.03 S 12 35 W 1859.86 S 15 2 W 1918.65 S 17 55 W !975.66 S 19 42 W 2030.6! 5 19 34 W 2084.36 S 19 4 W 2137.16 2 68 1 68 I 65 1 09 1 15 1 1~ 1 la 0 28 0 42 0 2~ 1585 15 S 343.09 E 1621 86 S 12 13 E 1653 1719 1781 1842 !902 1960 2017 2O72 2126 80 S 338.21 E 1688 02 S 11 33 E 21 S 330.68 E 1750 72 S 10 53 E 33 S 320.76 E 1809 97 S 10 12 E 22 S 308.44 E 1867 86 S 9 30 E 25 S 293.73 E 1924 79 S 8 47 E 67 S 276.51 E 1980 07 S 8 2 E 2! S 257.0! E 2033.52 S 7 16 E 55 S 237.28 E 2086.09 S 6 32 E 89 S 218.29 E 2138.06 S 5 52 5 9540.28 8967.70 8900.00 29 48 9655.49 9067.70 9000.00 29 47 9770.79 9167.70 9100.00 29 50 9840.00 9227.74 9160.04 29 50 S 18 41 W 2189.94 S 17 47 W 2242.84 S 17 37 W 2296.07 S 17 37 W 2328.03 0.38 0.17 0.00 0.00 2181.17 S 199.65 E 2190.29 S 5 14 E 2235.53 S !81.80 E 2242.91 S 4 39 E 2290.18 S 164.32 E 2296.07 S ~ 6 E 2323.00 S 153.91 E 2328.09 S 3 47 E DIRECTIONAL SURVEY COMPANY BP EXPLORATION FIELD PRUDHOE BAY WELL B-31 (44-31-11-14) COUNTRY USA RUN I DATE LOGGED 27 - JUN - 91 DEPTH UNIT FEET REFERENCE 74683 AJI InterprotaUons are opinions based on Inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any Interpretations, and we sttall rx~t, except In the case or gross or willtJII rtegllgence on our part. be liable or responsible for any loss, costs, damages or expenses Incurred or sustained by a.qyone resulting from any Interpretation made by any of our olficer~, agents or employees. These Interpretatlorls are also subject to our General Terms and CondltJons a~ set out In our current price Schedule. Noe'n-~ 1000 500 -1000 -1500 -2000 -2500 sou~ -~000 W~$T WELL' B-31 (44-31-11-14) (2105'SNL,1609'WEL,SEC 31,T11N,R14E) HORIZONTAL PROJECTION lIEF 74861 SO.N..~ =1 / 500 IN/FT -~000 -1500 -1000 -500 0 ,500 1000 1500 2000 FAST WELL-B-31 (44-31-11-14) (2105' SNL, 1609' WEL.SEC 31,T11N,R14E) VERTICAL PROJECTION' -1000 -500 0 0 500 1000 1500 :~000 2500 3000 176.00 PROJECTION ON VERTICAL PLA~E 3&4~,00 176.00 SC.e~..ED IN VER'~CAL DEPTHS HORIZ SCALE = 1 /500 IN/FT BP EXPLORATION PAD B (44-31-11-14) B 31 Controlled Drilling Consultants, Inc. CONTROLLED DRILLING CONSULTANTS, INC. P.O. Box 190560 Anchorage, Alaska 99519-0560 (90'7) 333-1552 May 6,1991 Mr. Larry Driscoll BP Exploration Pouch 196612 Anchorage, Ak. 99519-6612 RE: Magnetic Single Shot Survey Job No.A- 0491-026 Well: B-31 (44-31-11-14) Prudhoe Bay Field North Slope, Alaska Date of Survey: 4-26-91 to 5-6-91 Dear Mr. Driscoll' Please find enclosed the" Original" and four (4+ copies of our Magnetic Single Shot Survey on the above well. The method used in calculating this survey was Radius of Curvature. The depth of the survey was 500! to 9121'. Thank you for giving us this opportunity to be of service. Yours very truly, Controlled Drilling Consultants, Inc. Directional Supervisor HORIZONTAL VIEW B.R EXPLORATION . - WELL B-31 (44-:51-11-14) RADIUS OF CURVATURE MAGNETIC SINGLE SHOT SCALE: I" = I000' TVD = 8600' TMD = 9121' ALL DEPTHS SHOWN ARE TVD BP WELL B-3J JOB NO COMPUTER-- 07 ,~'- :~ 7'-2-' iNTERPOLATED VFILLIES FOR EVEN l OOO FEET OF MEASURED DEPTH, - ......................... TRUE HEASURED VERTICAL SUB DEPTH DEPTH SEA 0 0 20-00 2000 3000 3000 4000 4000 5000 4996 6000 5902 7000 g766 8000 7649 9000 8497 9i21 ~660 932, 2932 3932 4928 5834 6698 758i 8429, 8532, ~OTAL uuuRpir~RT~ / !0.85 S 2,86 E ...... 67,94 S i6.70 E ..... I 453,83 S i57,92 E I I 277,03 E . - ' t . ~ . I .... i 9:7;8,33 S i403.90 S i 926,66 $ i987,2i S BP WELL"B-31 HEASURED DEPTH 'r MEASURED DEPTH 7347 7461 7574 7687 7799 7910 802.2 81:35 8250 8369 8491 8611 $7~0 8848 8966 9087,, 9121 '" N ~.I GLE SHOT AND OTHER DATA FOR EVERY SURVEY TRUE VERTICAL SUB HD-TVD DEPTH SEA DIFFERENCE 7068, 7000 279 7168, 7100 292 7268, 7200 306 7368, 7300 718 7469, 7400 331 7568, 7500 342 7~68, 7600 354 7768, 7700 366 7868, 7800 382 7968 . 7900 401 8068, 8000 423 81 68. 8t O0 443 ~_~ 8zOO 462 8368, 8300 480 84~8, 8400 497 8568, 8500 515 8600, 8532 521 EVEN l NO A-049-I-026 COMPUTER- t'g?' HAY 9~. JO8 KB ELEV 67.72 FT, I TOTAL -' CO0'RDINRTES ....................... t 106 7~ S ~"~'~' ..... ~i60,t4 S - -325'~78 ~ 2~2 88 S -333~!-0 E ............ 1264,69 S 339;3~ E ............ s ..... e .............. t465 98 9 -- 7~9',78 E .............. I I%2~, 47 S ' 349,79 E .............. 1588,2 O' S- 3-48T2~ E ........... I 1-787; 17 S .... 3~7-,~5 '~ " i 8~8 ;-8 t' -S .... ~1'5'7-i%~ -E ........... !909.21 8 3'00';5-! E .......... I968,4~ $ - 28~;29-5 ............... i987,2I ~ -2~7,-0-7 E ........ ...... ............................... ................. ........................................... ........... ................. t00 FEET OF SUB SEA DEPTH, VERTICAL CORRECTION 15 i3 !2 13 11 I2 i2 !9 22 20' i7 i8 BP WELL B-31 MEASURED DEPTH . · . ; HEASURED DEPTH 3568 3668 3768 3868 3968 4068 4168 4268 4368 4468 4568 4668 4769 4870 4972 5074 5179 5285 5392 5502 56;5 5729 5845 5960 6076 6191 6307 6423 6538 6654 6770 6886 7002 7118 7233 AND OTHER DATA TRUE VERTICAL SUB DEPTH SEA SINGLE SHOT SURVEY JOB NO A-0491-026 CU[IFUTER- 07 MAY KB ELEV 67,72 Fi', FOR EVER".,' EVEN 100 FEET OF SUB SEA DEPTH, HD-TVD DIFFERENCE 3568, 3500 0 3668. 3600 0 3768, 3700 0 3868. 3800 0 3968, 3900 0 4068, 4000 0 4168, 4100 0 4268. 4200 0 4368, 4300 0 4468, 440O 0 4568, 4500 0 4668. 4600 0 4768. 4700 0 4868, 4800 4968, 4900 5068. 5000 6 5168, 5100 5268, 5200 I6 5368, 5300 24 5468, 5400 34 5568, 5500 47 5668, 5600 61 5768, 5700 77 5868, 5800 92 5968, 5900 I08 6068, 6000 i23 6168. 6100 t39 6268, 6200 154 6368, 6300 170 6468, 6400 186 6568, 6500 202 6668. 6600 2J8 6768. 6700 234 6868, 6800 250 6968, 6900 264 VERTICAL CORRECTION - TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 5 5 8 10 i4' 16 !6 I5' !6 !5 16 I6 !6 !6 !6 !4 ~, 46 'S 4-;55--E i0.-t5 8 ..... ~v~3 E- l 0;69--S ...... 2;-~7 E t 6T;97 8" -i-5 :Ct6 E ......... t f i 4,14 ~ '--3-T;'6~ - - !84,67' S .... 53 F7¢ E ................... 276.03 S .... ~8;x~8~ E ..... I 327,64 S ' '-i~:~4 E ............... l I - t ~-~-~-'~' ......................... I l 9~, 52 S- 291-;6~ E ........ 996,37 -8 - 30t72~- E ................ l I BP UELL"~B-31 SINGLE SHOT SURVEY JOB MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN t00 FEET OF TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION 0 168 268 368 468 568 'i068 1168 I268 1368 1468 1668 I868 t968 2068 2268 2368 2469 2568 2668 2768 2868 2968 3068 3268 3468 O, --68 0 0 168, 100 0 0 268, 200 0 0 368, 300 0 0 469, 400 0 0 568. 500 0 0 668, 600 0 0 768, 700 0 0 868, 800 0 0 968, 900 0 0 1 068, 1000 0 0 I168, 1100 0 0 1268. 1200 0 0 $368, 1300 0 0 I468, ~400 0 0 1568, J500 0 0 i669, 1600 0 0 1768, 1700 0 0 1868, ~800 0 0 1968, J900 0 0 2068, 2000 O 0 2f68, 2100 0 0 2268, 2200 0 0 2368, 2300 0 O 2468, 2400 0 0 2568, 2500 0 0 2669, 26OO 0 0 2768, 2700 0 0 2868, 2800 0 0 2968, 2900 0 0 3068, 3000 0 0 3168, 3100 0 0 3268, 3200 0 0 3368, 3300 0 0 3468, 3400 0 0 NO R-049!-026 COMPUTER- C'.~ HA".,' 91 KR_ ELE'J. 67,~'':< FT., SUB SEA DEPTH, _ COORD TOTAL ' ' .... ~ .................... ,OO-S - ,00 b~ .............. i5 N " .86' N.. '-' ~- ,~..~ E: ............ ,52 S -' I ;-O~ E ....................... '2,54- S ~,i7 S ..... ! ~0 'E ....................... 3; 65 S ...... !"; 28 -E ..................... ~;95 S '- 4,09'8 4,27--'~ ....... i ,00- E ................... - ' ' ....... 1 3,77 -S /1'8' S .... T73 ~,r ............................. ,60--N - --:75 [;i .............. 1,56, N i-,~i -~ ............ 2 62-S - -' 3,6~ S ' '-6-', ~:!" E ....... : ........... l 4-;-61 S .... 6,~7 'E ......... . ................... '5,-44' S -- - -6f29 E ............... ~ ;q '6--S--* -6'%~8 E ........................ ................ 6 8I S '5782 E 7;~I c--' '5-47 ~ ......................... 7,95 -S - -' 5--;-0~- E ........ ....................................... ......................... BP NELL · '3INGLE SHOT SURVEY JOB, NO A-": "~ ue.~l -026 COHPUTER- 07 NAY 9i KB ELEV 67 7o ~ .. / HE~S, DRIFT , DEPTH ANGLE .~477 5570 · . 5787 ,. 5976 6258 ' 6545 ~,, 6627 -.,,6816 :, 7005 ':: 7192 ,;~ 7379 7570 -?7760 -..~. 7948 · .u8148 :,~,,'3329 ~.. .' .- ~ D M 25 30 30 30 30 30 30 30 29 28 27 26 25 28 35 32 31 · ' 9080 31 ,:~ THE FOLL -912I 31 30 ,~-BOTTOM HOLE -, TRUE VERTICAL SUB DEPTH SEA RECORD OF SURVEY DRIFT DIREC 54 5361 ,00 5293,28 S20.30E 18 5444 , 97 5377,25 S20,60E 0 5528,08 5460,36 S2i . OOE 6 5717,77 5650,05 S21,70E 6 5881 .29 5813,57 S2i,OOE 6 6125,26 6057,54 S2~. 30E 0 6373,68 6305,96 S!3,90E 30 6444,52 6376,80 SI O. 40E 48 6607, i 1 ~53'B, 39 Si O. 80E 12 6769 , 96 6702 , 24 Si O, i OE 24 6932,23 6864,51 S 8,30E 24 7095,94 7028,22 S 8,70E 54 7264,35 7196,63 S 7,60E 48 7433,1 I 7365,39 S 5,20E 48 7601,64 7533,92 S 2,00E 30 7772 . 47 7704 , 75 S , 60E 30 7934,43 7866,7~ S i,50W 12 8008,73 794i,0t S 3,60W 0 8164,39 ~096,67 S 6.80W 6 8323.70 B255.98 S1 i , 70W 42 8484,16 8416,44 Sl 4,90W · 36 8565.03 8497,31 SiS, OOki OWING IS EXTRAPOLATED TO TO 8599 , 97 ~532 , 25 S! 8,80W CLOSURE 2006,43 FEET AT S TOTAL COORDINATES 2t7,i9 354,3I 442,59 ~74,49 711,39 75!,77 846,47 940,80 i 032.54 1~2i,92 12ii,12 1297,86 !380 98 I468 56 J565 86 172i 5~ 182I 87 19i9,05 1966,86 1987,2I 756 iO E C 'L -O- S -U- P..-E- S .... SEVER 52,8 0 'E 1 8~; 5 O'S -1 ~.---!~- 4 ~'E .... 2-;71-0 65 93 E 8 O, 74 E - 119,I0 E 353 60 E 468 49 S-'!9 '-8-22-'E-- '~i86' , ' R ....... 0 ...... 204' 63 E 248, 256,75 E 794-;-40' S ~8-~-23 E - I ;25-7 29i ,87 E ' 3 06,73 E 320,.09 E 332.86 E 342,59 E' 347;82 E 349.8-I -E 349,04 'E 346,79 E 337,23 E 320,89 'E 297,92 E 283,8! E '!077~!4 S ~'~; -7,2 4t E- · .:487 .... 067,3~. j ] i 166-;'-69- S- 1-5- -~5 -;=~--E7 ....... ,-55? ...... t~>--;--~ .... 'J..509; 65- $- i-3-'2~ -~--E - - i~, ¢,-1~. .... ,~. ~. ,. . --c~-, ,~,.~ -- 160~, 2~S -! ~ 3-3-58 -'E ..... ~,=, _ ~,"~-~ .... ~608. :. 8~-. -I~-~25 S -I t- -~-... O '~ - 1-T27~ -'752-;89 ! 849 ;-9 ! -S .... 9 -59 2'1~ -E ....... ,-873 ..... !-8'49~ 5-S ...... 19~2;-04 -S- -- 8--49 -~7-E .... ;-'~ 3 ' - - ! 942 ;~ -- BP EXPLORATION HAGNETIC SINGLE SHOT SURVEY RADIUS OF CURVATURE METHOD OF ENGINEER C.W, HARRINGTON r~ COPIPUTED FOR CDC BY ARCTIC . r-PTH ANGLE ~EPTH D H ,! ~SSURED VERTICAL TO TRUE HEiqS~ DRIFT VERTICAL 0 30 0 30 30 45 36 24 24 24 18 12 6 36 6 24 12 54 48 30 24 499 985 1492 2475 .,,.,, 3164 3474 3827 4136 4406 4531 4625 4718,43 4812,6'? 49 03.46 4993 5 084,64 5186,87 5274,56 ~._. 500 0 986 0 ]493 0 .:~ 2476 0 2822 3165 0 ., ,,,-3475 0 382'8 0 ·. :. 4137 0 .., 1.07 0 ~..4.6;26 3 4719 6 >, 4.814 8 -.. 4.906 1'0 4998 12 -... 5092 15 ~,- 5199 18 -5292. 20 ,''r . _ . 44 O0 99 99 98 96 93 91 90 89 88 87 87 86 78 SUB SEA 0 F -67, 432, 9t8, t425, 1 922, 2408, 2754, 3097, 3407, 3760, 4069, 4:339, 4464, 4.558, 4650, 4744, 4835, 4925, ~'01 ,' · .' :2' f 5119, 5206, COHPUTATiON StOPE CONSU~'~ . ~,ING GROUP RECORD OF SURVEY DRIFT DiREC DEG, 72 N ,00E 27 822, OOE 27 S ,00E 26 N41,0 OW 24 N62,00E ' 21 844,00E 19 S 5,00W 18 817, OOW 17 S44~40W 831 ,80W 1.5 S38,1 'OW 15 NSl ,80W 14 825,20E 06 S19,20E 71 816,10E 95 Si 5, OOE 74 Si5..70E 86 SI5,40E 92 S15,70E I5 SI?,80E 84 81-9,20E TOTAL COORDINATES ,00 $ 2,02 $ 4.09 S 2,42 8 1,23 N ,52 N .3.2! S 6,t4 8 7,98 S 9,92 S I1,47 S Ii,88 $ !2,82 S 16,38 S 23:87 8 35.42 8 49,76 S 67,50 S 89,95 8 120,16 S 149,61 S JO8 NO A-0491-026 WELL KB ELEV 67,72 FT, SURVEY DATE'26?04?9! ............ I PROPOSED 0 i R- - S'08--- SE- .................... 1 1 .... -_ -_-. __-- _- ......... DO~- -LEi] ..... ~..r' L O-S U'-'R E--c:._- ...... SEVERTTY-_ SECT D-!S T~NCE ..... RiO] k~ .... DEG~¢I-'SOPT ..... O i-S TA NCE- " ........... fj -~,+- ~ ....................... .................... :. -_L_. ,0-0 W- ,-00 S'90--~7 - O--W .... ~--O-OO' - ';00 - i, co E ' 4 .-2%~-' ~-i6 - 3~ '~4 .$-~- E - ~ ..... '~ .......... ~-~'~3- -- I / ~ [,} -- -~ ;43- S- -'5-'2~-~ I'- W ...... 099 - 46 E 1,37 'tq 19 27-~ - · ...... ~ .......... 6,66 E 7-,~ 8'64 !5-49-E - - ;0'43 ....... 2,39 E 'Ii ,7~--8 !!- -4~-i2-~ .... ,032 -i+- ~-n-; ' 1,35-E- - ii-,96 S- ~--~ 25--E ,037 .... 2 I 1 b i6;52 ~ '-~7--2¢-i-~---'E ...... 2766¢ - l il 65 E 51-;1~ S-13- !0-26 E .... ~ '-- 't6,~8 E 69,5i-S i3'-48' it E ...... 2 9~ - --69,25 - t I ' -.'_- ':_ .'::--:-':'..' -_:-:. TELECO OILFIELD SERVICES SURVEY CALCULATIONS Date 05/06/91 company: Well: Location: Rig: BP EXPLORATION B-31 PRUDHOE BAY NABORS 18E TELECO Job # Grid Correction: Magnetic Declination: Total grid correction: Proposed Direction: 820TAK 0.0° 30.0? 30.0° 171.5° MINIMUM CURVATURE CALCULATION Meas Course True Vertical Coordinates Closure Dog Leg. Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100° TIE IN TO SPERRY SUN GYRO SURVEY 2476 0 0.8 136.0 2475.93 0.23 0.62N 5.73E 5.76 N 83.82E 0.00 TELECO MWD 2822 346 0.6 185.0 2821.91 3.84 2.81S 7.14E 7.68 S 68.50E 0.17 3165 343 0.4 197.0 3164.90 6.66 5.75S 6.64E 8.78 S 49.liE 0.07 3475 310 0.4 224.4 3474.89 8.29 7.56S 5.56E 9.38 S 36.37E 0.06 3828 353 0.4 211.8 3827.88 9.98 9.48S 4.05E 10.31 S 23.14E 0.03 PAGE 1 · Company: BP.EXPLORATION, Well: B-31, Location: PRUDHOE BAY, Riq: NABORS 1SE Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100° ******************************************************************************************************* 4173 345 0.3 218.8 4172.87 11.51 11.21S 2.85E 11.57 S 14.27E 0.03 4407 234 0.2 278.2 4406.87 11.81 11.63S . 2.06E 11.81 S 10.06E 0..11 4532 125 1.1 154.8 4531.86 12.89 12.68S 2.36E 12.90 S 10.53E 0.98 4626 94 3.6 160.8 4625.78 16.66 16.29S 3.71E 16.71 S 12.84E 2.67 4719' 93 6.1 163.9 4718.44 24.43 23.79S 6.04E 24.55 S 14.25E 2.70 4814 95 8.4 165.0 4812.67 36.33 35.35S 9.24E 36.54 S 14.65E 4906 92 10.2 164.3 4903.46 51.08 49.68S 13.18E 51.40 S 14.86E 4998 92 12.9 164.6 4993.59 69.36 67.43S 18.11E" 69.82 S 15.04E 2.43 1,96 2.94 5092 94 15.8 164.3 5084.65 92.48 89.87S 24.37E 93.11 S 15.17E 3.09 5199 107 18.5 162.2 5186.88 123.69 120.06S 33.50E 124.65 S 15.59E 2.59 5292 93 20.4' 161.8 5274.57 154.23 149.51S 43.07E 155.59 S 16.07E 2.05 5385 93 22.9 159.7 5361.00 187.92 181.88S 54.41E 189.85 S 16.66E 2.81 5477 92 25.3 159.4 5444.98 224.67 217.08S 67.54E 227.34 S 17.28E 2.61 - 5570 93 28.0 159.0 5528.09 265.43 256.08S 82.36E 268.99 S 17.83E 2.92 PAGE 2 Company: BP EXPLORATION, Well: B-31, Location: PRUDHOE BAY, Riq: NABORS 1SE Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity -feet feet deg deg feet feet feet feet feet deg deg/100° 5693 123 30.0 159.0 5635.65 323.66 311.77S 103.73E 328.57 S 18.40E 1.63 5787 94 30.1 158.3 5717.01 369.56 355.61S 120.86E 375.59 S 18.77E 0.39 5881 94 29.8 160.4 5798.46 415.43 399.52S- 137.41E 422.49 S 18.98E 1.16 5976 95 30.1 159.0 5880.77 461.85 444.00S~ 153.86E 469.90 S 19.11E 0.80 6069. 93 30.5 159.4 5961.07 507.69 487.86S~ 170.52E 516.81 S 19.27E 0.48 6163 94 30.2 158.6 6042.19 554.06 532.21S 187.54E 564.28 S 19.41E 0.54 6258 95 30.1 158.7 6124.34 600.58 576.65S 204.91E 611.97 S 19.56E 0.12 6351 93. 30.1 158.7 6204.79 646.06 620.10S 221.85E -' 658.59 S 19.69E 0.00 6461 110 30.3 159.4 6299.86 700.09 671.78S 241.64E 713.91 S 19.78E 0.37 6545 84 30.0 166.1 6372.52 741.73 712.01S 254.14E 756.01 S 19.64E 4.02 6627 82 30.5 169.6 6443.35 782.95 752.39S 262.83E 796.97 S 19.26E 2.23 6721 94 31.0 168.2 6524.13 830.96 799.55S 272.08E 844.58 S 18.79E 0.94~' 6816 95 30'.8 169.2 6605.65 879.70 847.40S 281.65E 892.98 S 18.39E 0.58 PAGE 3 .ComDany: BP EXPLORATION, Well: B-31, Location: PRUDHOE BAY, Riq: NABORS 18E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100° ******************************************************************************************************* 6910 94 30.5 168.9 6686.51 927.57 894.45S 290.75E 940.52 S 18.01E 0.36 7005 95~ 30.2 169.9 6768.50 975.54 941.63S 299.58E 988.14 S 17.65E 0.62 7098 93 29.7 170.6 6849.08 1021.96 987.39S 307.44E 1034.15. S 17.30E 0.66 7192 94 29.4 171.7 6930.85 " 1068.31 1033.19S 314.58E 1080.02 S 16.93E 0.66 7285 93 29.0 171.7 7012.03 1113.69 1078.09S 321.13E 1124.91 S 16.59E 0.42 7379 94 28.4 171.3 7094.48 1158.84 1122.75S 327.80E 1169.62 S 16.28E 0.68 7475 96 27.9 -171.7 7179.12 1204.13 1167.54S 334.50E 1214.51 S 15.99E 0.56 7570 95 27.9 172.4 7263.08 1248.58 1211.57S 340.65E" 1258.54 $ 15.70E 0.34 7665 95 27.4 173.8 7347.23 1292.65 1255.33S 345.95E 1302.12 S 15.41E 0.86 7760 95 26.8 174.8 7431.80 1335.87 1298.39S 350.25E 1344.80 S 15.10E 0.79 7855 95 26.5 176.3 7516.71 1378.37 1340.87S 353.56E 1386.70 S 14.77E 0.78 7948 93 25.8 178.0 7600.19 1419.16 1381.80S 355.60E 1426.82 S 14.43E 1.11 8046 98 26.0 177.3 7688.34 1461.73 1424.58S 357.35E 1468.72 S 14.08E 0.38 PAGE 4 · Company: BP EXPLORATION, Well: B-31, Location: PRUDHOE BAY, Riq: NABORS 1SE Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet.~ deg deg feet feet feet feet feet deg deg/100° 8140 94. ~28.5 179.4 7771.90 1504.45 1467.60s 358.56E 1510.77 S 13.73E 2.84 8234 94 30.9 180.5 7853.55 1550.52 1514.17S 358.58E 1556.05 S 13.32E 2.62 8329 95. · 33.5 181.5 7933.93 1600..44 1564.78S 357.68E 1605.14 S 12.88E 2.79 ~8419 90"'35.2 183.6 8008.23 1650.27 1615.50S 355.40E 1654.13 S 12.41E 2.30 8513. 94...34.0 185.7 8085.61 1702.25 1668.70S 351.09E 1705.24 S 11.88E 1.79 8607 94 "33.0 186.8 8163.98 1752.44 1720.29S 345.45E I754.63 S 11.35E 1.24 8701 94-'~32.1 189.3 8243.21 1800.92 1770.36S 338.38E 1802.41 S 10.82E 1.73 8796 95.-_ 32.1 191.7 8323.69 1848.65 1819.99S 329.18E-' 1849.52 S 10.25E 1.34 8890 94 32.0 192.4 8403.36 1895.36 1868.78S 318.77E 1895.77 S 9.68E 0.41 8985 95. 31.7 194.9 8484.06 1941.80 1917.49S 306.94E 1941.91 S 9.09E 1.43 9080 95 - 31.6 198.0 8564.93 1986.98 1965.29S 292.83E 1986.98 S 8.47E 1.72 9121 41 31.5 198.8 8599.87 2006.11 1985.64S 286.05E 2006.14 S 8.20E 1.04 PAGE 5 T¢'_ECO Oilfield Servi~'"~s PLAN VIEW 4OO 2476 ' 5092 ' 5385 ' 5693 5B81 ' 6069 ' 6258 ' 646! 6627 ' 7005 ' 7192 ' 7379 ' 7570 ' 7?50 7948 8140 8329 870i ' 8890 ' 9121 ' BP EXPLORATION B-31 PRUDHOE BAY NABORS 18E JOB# 820TAK/O0 SCALE: I inch = 400 feet 400 800 1200 15oo C 2000 2400 2800 3200 400 8OO EAST 2~fOt) 1600 2000 2400 2OOO --CO Oilfield Service( VERT I C AL PROJECT I ON 0 lO00 2000 3000 4000 5000 6000 3000 4OOO ~]~000 W °6000 >7-000 8OOO 9O0O lO000 ~iooo 2476 ' .75 deg 2622 ' .6 deg 3165 ' .4 deg 3475 ' .4 deg 3828 · .4 deg 4173 ' .3 Oeg 4407 ' .2 deg 4626 ' 3.6 Oeg BP EXPLORATION B-31 PRUDHOE BAY NABORS JOB# 820TAK/O0 SCALE: 1 inch = lO00 feet k4906 ' 10.2 deg 5199 ' ~8,5 deg 5477 ' 25.3 deg 57B7 " 30.1 deg . 6069 ' 30.5 deg .%635~ ' 30.1 Oeg %6627 ' 30,5 deg %6910 ' 30.5 deg 7192 ' 29.4 aeg -]~7475 ' 27.9 deg -~77~0 ' 26.8 deg -I~k8046 ' 26.01 deg 8329 ' 3~.5 deg 6607 ' 33.01 Oeg VERTTCAL SECTION (ft) PERMIT # ~ - COMPLETION DATE AOGCC GEOLOGICAL MATERIALS INVENTORY LIST ~ ~ WELL NAME f),._..~U. J'~"" 3 I (~ t_ .2TI I ell CO, CONTACT ~)pL~ i check off or Ii~t data as it is received.*list receiv(~d date for 407. if not re.quired list as NR ,or I.~ll~lq~drilling history ~" ..-m;l'~ ! ,~,,t..t. ~ lcor, d,scrirtiod,..v. cored IntErval's , core analysis ~. d~ ditch intervalsdigital data , ,,. ..... , ~f~ ,~tr .... LOG TYPE RUN INTERVALS SCALE .......... NO., ,,,[to the neareot · r -; .i I I Iii IJ '' Illl I III Jl I IIII I I J I I ....... I ....... III -~ lUU i . . ui i i i .......... ~nl ~C/~ I~ ............ ~ qlw~~X~ ............ , .................. , .......... : 111 ' " ..........~ ~! ........................... I _ IIIII III III II II II I I I I I IJll IIIIIIII II I I t , .ltl i ii iI III I III I I I I ... I III I . I~ 1111! ...... ~ [1!11 , 1. .......... . ~ Illl IIlI I I J J I I I I ItlJ I II II Illl i ii iii , i i ii 11111 i i iii i i ii i ...................... BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: ARCO CHEVRON EXXON MOBIL PHILLIPS STATE OF ALASKA TEXACO GEOSCIENCE ARCHIVES BP OPEN HOLE FINAL Date:05/21/91 T#:82458 RECEIVED S ~ P 1 9 0il & (~as Cons. c0mmissi~.n Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. B-31 BHCA/GR 05/09/91 #1 9173-9803 ATLAS 2"/5" B-31 CNL/GR 05/09/91 #1 9173-9775 ATLAS 2"/5" B-31 DIFL/GR 05/09/91 #1 9173-9832 ATLAS 2"/5" *** GEOS/ARCO/EXXON/ARCH IVES ONLY. B-31 SSTVD 05/09/91 #1 9173-9832 ATLAS 1 "/2" STATE ONLY: Magnetic Single Shot Directional Survey Date: Gyroscopic Directional Date: Job#: Job#: Inforation Control Well Records LR 2-1 J..Dietz/S. McCurry BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :07/08/91 T#:82565 FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. E-02 N-11A W-37 PFC 06/28/91 #1 9265-9555 Atlas 5" CL 07/01/91 #1 9736-9942 Atlas 5" Production 07/03/91 #1 10100-10580 Atlas 5" CN/GR 07/01/91 #1 9600-10206. Atlas 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: ARCO EXXON PHILLIPS STATE OF ALASKA ARCHIVES DATE:05/23/91 T#: 82464 SYSTEM Iap. e & Transmittal Only BP. MAGNETIC. LIS TAPE & LISTING Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. CASED HOLE TAPE: J-17 'CNT-D 05/18/91 SCH#74574 1600BPI 9995-10948 TAPE POS.#07763 AP1#50-029-20969 QPEN HOLE TAPE: DIFL/BHC-AL/GR 05/09/91 ATLAS# 1600BPI :~~[{ P-06 DIFL/BHC-AI. JGR 05/19/91 ATLAS# 1600BPI 7920-9860 TAPE POS.#07764 AP1#50-029-22152 . 7750-10440 AP1#50-029-22166 TAPE POS.#07765 Information Control Well Records LR 2-1 J. Dietz BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date: 05/22/91 T#:82460 FROM: SUBJECT: Information Control Well Records LR2-1 BP GA,~ED HOLE FINAL~; Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. *B-31 CBT 05/13/91 #1 7600-9755 SCH 5" CET 05/13/91 #1 8891-9782 SCH 5" * THERE ARE NO SEPIA PRINTS OR A FILM AVAILABLE ON THE CET LOG. Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES RECEIVED ~Jaska 0il & Gas CoJ~s. ~j~.~,,~ TO: THRU: MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smlv~,~. ,~ DATE: May .28, 1991 Commissioner .. FILE NO: DA528 TELEPHONE NO: SUBJECT: BOPE Walk-thru inspc BPX PBU B-31 Nabors Rig 1SE Prudhoe Oil Pool FROM: Doug Amos Petroleum Inspector sunday May 3.. 1991: I travelled this date from AAI KRU to BPX PBU B-31 to conduct a BOPE walk-thru inspection on Nabors Rig 1SE. On a previous walk-thru inspection, item #22 on the attached AOGCC BOPE walk-thru Inspection Report was not in compliance. I found this item in compliance at this time. I found no other non-compliance items during this walk-thru. In summary: I conducted a BOPE walk-thru inspection on Nabors Rig 1SE. I found all items in C6~"liance. Attachment. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 OPERATION: Drlg/ ~' Wkvr Operator Locati on.- Sec Drlg contr Location (gen'l) ~ N COMPL yes no n/a A. DIVERTER 1.() () 2.() () 3.() () 4.() () s.() () 6.() () 7. ( ) ( ) 8.(~ () 9. (~ ( ) lo. (~)~ () ~l. (~" ( ) ~2. (~'"' ( ) ~3. (~)~ () 14. (~' () STATE OF ALASKA ALASKA 0 i L AND GAS CONSERVAT I ON COMM I SS ! ON BOPE Walk-Thru Inspection Report UlC ~ Permit # ~/'~ Ri g #_J_~ Well sign ~/~ line sz & length line corm & anchored bifurcated & dwn wind 90° targeted turns V 1V S : auto & simultaneous annul ar pack-off condition B. BOP STACK wellhead flg wkg press stack wkg press annul ar preventer pi pe rams blind rams stack anchored chke/kill line sz Well name ~-~/ Representati ye ~'~. ~? / IN COMPLIANCE; yes no n/a 33. (~F ( ) 34. (~ () 35. ('~'"' ( ) 36. ,(~j~ ( ) 37. (~[ ( ) 38. (~' () 39. ((~ () 40. ( ) 41. ((~ ( ) 42. ( ) 43. (~F~' ( ) 44. (~)~ ( ) 43.(~ () firewall nitrogen power source (back-up) condition (leaks, hoses, etc) D. MUD SYSTEM pit level floats installed flow rate sensors mud gas separator degasser separator bypass gas sensor chke In corm trip tank E. RIG FLOOR kelly cocks (upper,lower, IBOP) floor vlvs (dart vlv, ball vlv) 16. (~)~' ( ) ( ) HCR vlvs (chke & kill) 17. (~)/~' ( ) ( ) manual vlvs (chke & kill) 18. (b(~ ( ) ( ) connections (flgd, whd, clmpd) 19. (~' ( ) ( ) drl spool 20. (v~" ( ) ( ) flow nipple 21. (b~, ( ) ( ) flow monitor 22. (~ ( ) ( ) control lines fire protected C. CLOSING UNITS 23. (~'~ ( ) ( ) wkg press 24. (~¢ ( ) ( ) fluid level 25. (~ ( ) ( ) oprtg press 26. (~' ( ) '( ) press gauges 27. (~" ( ) ( ) sufficient vlvs 28. (~,~ .... ( ) ( ) regulator bypass 29. (.~)" .....( ) ( ) 4-way vlvs (actuators) 30. (~'i ( ) ( ) blind handle cover 31 (~ ( ) ( ) driller control panel 32 (~ ( ) ( ) remote control panel ( ) 90° turns targeted (chke & kill ln) 46. (~ ( ) ( ) kelly & floor vlv wrenches 47. (~' ( ) ( ) driller's console (flow monitor, 48. (,,,r' () 49. (~" () st. 52. (~' ( ) flow rate indicator, pit.level indicators, gauges) ( ) kill sheet up-to-date ( ) gas ~etection monitors (H-S & methane) ( ) hydr chke panel ( ) chke manifold F. MISC EQUIPMENT ( ) flare/vent line 53. (H'" (). ( ) 90° turns targeted 54. (') ( ) 55. (V)'" ( ) 56..( V,),, ..... ( ) 57. (~,.. ( ) 58 ( () (dwn strm choke lns) (~*'reserve pit tankage ( ) personnel protective equip avail ( ) all drl site suprvs trained for procedures ( ) H2S probes ( ) rig housekeeping REMARKS: RECORDS: Date of last BOP inspection: ~.//~/¢/ Resulting non-compliance: /~/~/~ Non-compliances not corrected & why: Date corrections will be completed: Date of last BOP test: BOP test & results properly entered on daily record?~ Kill sheet current? Inspector C.0013 (rev 04/29/91 ) PE - 5948 ZCZC BP EXPLORATION PRUDHOE BAY, ALASKA 5/18/91 TO: OLDENBURG/LIT'rLEFIELD FR: LINDER/O'MALLEY RE: B-31 SWS NABORS 18-E CASING LOG DRLG, 5 / 13 / 9 1 COMPLETION 1300 RIG UP SCHLUMBERGER UNIT 2005. R1H WITH CET/CBT/GR/CCL TO LOG 7" CASING FROM PBTD TO LINER TOP. MADE TIE IN PASS REFERRED TO BHC ACOUSTILOG DATED 5/9/91. LOGGED FROM PBTD AT 9790' TO LINER TOP AT 8891'. CEMENT LOG SHOWED EX(Y.I.LENT CEMENT FROM 9790' TO 9350'. GOOD TO FAIR CEMENT FROM 9350' TO 9300'. SPOTTY CEMENT FROM 9300' TO 9178'. CEMENT IMPROVED FROM SPOTTY TO GOOD FROM 9178' TO LINER TOP AT 8891'. RIH WITH CBT/GR/CCL. RELOGGED 7" LINER WITH CBT DUE TO LOW TRANSMITTER VOLTAGE. MADE TWO PASSES. MADE ADDITIONAL PASS AT 4000' PER HOUR TO PICK UP COLLARS. NOT MUCH BETTER WILL PRESENT CCLV FOR BETTER CLARIFICATION DROPPED DOWN 100' INTO 7" AT 8990' START CBT/GR./CCL LOG RUN OF 9-5/8" CEMENT LOG SHOWED. POOR TO MARGINAL UP TO AT 7600' STOPPED LOG 9-5/8" LOGGED AT 1800' A HOUR. POH. R.D. SWS. 1800 RIH WITH DRILL PIPE WITH POLISH MILL AND 9-5/8 CSG 5/14/91 SCRAPER. POH. LAY DOWN DRILL PIPE. 0600 RIH WITH 7" TUBING WITH DUMMY SEAL ASSEMBLY 7" "R" NIPPLE AND PACKER 9-5/8" (SABL) WITH TBG ANCHOR 7"~ L-80 I-J4S TBG. 1530 RIH WITH 7" TBG, MADE UP SSSV TEST CONTROL LINE TO 5000 PSI. RIH WITH 7" BLANKING SLEEVE IN NIPPLE. 1750 WHEN LANDING TBG. SPACE PUP JOINT "A" (10.60) AND 3 PUP'S ADDING UP TO (5.10), USED SS BANDS ALL WAY UP FROM SSSV ONE ON EVERY OTHER JOINT USED TWO ON SSSV NIPPLE AND 2 ON HANGER FOR A FULL AMOUNT OF (30-SS BANDS.)~ 1800 TESTED THROUGH FMC TUBING HANGER EACH LINE 15 MIN. LANDED TUBING~ SET 2-WAY CHECK. 2000 NIPPLE DOWN STACK NIPPLE UP 6" CAMERON TREE. 5/15/91 0400 TEST SEAL ON HANGER 15 MIN AT 5000 PSI. BLED DOWN 50 PSI, GOOD, R.V. TEST BALANCE AND CONTROL AT 5000 PSI 15 MIN TESTED GOOD. 0530 R.U. TEST TREE 5000 P. SI 15 MIN GOoD R.V. PULL 2-WAY CHECK. 0600 R.U. AND DISPLACE 128 BBLS OF DIESEL DOWN TBG. ALLOW TO U-TUBE., 0900 DROP BALL AND ROD. ALLOW 30 MIN TO FALL R.V. PRESSURE UP TBG ET PACKER TEST TUBING 3000 PSI R.V. ON ANNULUS SIDE PRESSURE ;UP TO 2700 PSI WITH AOGCC MAN TO WITNESS FOR 30 MIN. GOOD TEST. 1000 R.U. SET BACK PRESSURE VALVE. ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 April 8, 1991 Bill Kirton PBU Lead Engineer BP Exploration (Alaska), Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit B-31 BP Exploration (Alaska) Inc. Permit No. 91-46 Sur. Loc 2106'SNL, 1611'WEL, Sec. 31, TllN, R14E, UM Btmhole Loc 4440'SNL, 1272'WEL, Sec. 31, TllN, R14E, UM Dear Mr. Kirton: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The mechanical integrity of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3) before operation. Please contact the commission at least 24 hours before pressure testing so that a representative of the commission may witness the test. irman Alaska Ofl~a~d Gas Conservation Commission BY ORDER O~THE COMMISSION dlf/Enclosures c: Department of Fish and Game, habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.0O5 la. Type of work Drill [] RedrillDIlb. Type of well. Exploratoryr-1 Stratigraphic TestF1 Development OilE] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exoloration KBE = 64' feet Prudhoe Bay Fieid/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchorage. Alaska 99519-6612 ADL P~310 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o ,,,Ac 25.025) 2106' SNL, 1611' WEL, SEC. 31, T11N, R14E Prudhoe Bay Unit At top of productive interval 81 Well number Number 4250'SNL, 1300' WEL, SEC. 31, T11N, R14E B-31 (44-31-11-14) 2S100302630-277 At total depth 9. Apprr_~x_.!m~ate_.~spud date Amount 4440'SNL, 1272' WEL, SEC. 31, T11N, R14E ,.. 'April 18, 1991 · $200,000.00 12. Distance to nearest 13. Distance to nearest we ll'-l¢.-NLimber of acres in property15. Proposed depth(MD and TVD) property line ADL 28286 ~838' feet B-lO @ 3017'/18' feet 2560 9817'MD/9213'TVDf e e t 16. To be completed for deviated wells 17. Anticipated .pressure (see 20 AAC 25.o35 (e)(2)) Kickoff depth ,~soo'feet Maximum hole angle 2g.9 o Iaaxlmum surface 3330 pslg At total depth (TVD) 8800'/4~g0 pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" Cond. 80' Surface 110' 110' 17-1/2" 13-3/8" 68# L-80 Butt 2650' Surface 2680' 2680' 3723 cu fl Permafrost 12-1/4" 9-5/8" 47# L-80 NSCC 9096' Surface 9126' 8615' 1866 cu fl Class G 8-1/2" 7" 26# L-80 NSCC 941' 8876' 8334' 9817' 9213' 240 cu ft Class G 19. To be completed for Redrill, Re-entry, and DeePen Operations. Present well condition summary Total depth' measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface RECEIVED Intermediate Production1991 Liner Perforation depth: measured ~Ja$~ 0il& Gas Cons, true vertical ....../' '-~ 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Div'~l'te'¥"'~k'~{'~h"E1 Drilling program [] !Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements.E] 21..I hereby cer~y t~at t~he f~regoing,,~/~-r-/~ -,~j-/~ is true and correct to the best of my knowledgez//,.~,//~/ Signed . Title PBU Lead Engineer / Date Commission Use Only ~ / Permit Number IAPI number IApproval date See cover letter ~/-/-/'G" [5o-o~.?- z z./5-.2_. I 04/08/91 for other requirements Conditions of approval Samples requ, ired [] Yes .,I~NO Mud Icg requir,ed I-lYes ,,'1~ 'No .... HydrOgen sulfide measures [] Yes ~ No Directional survey requ~re~ ,,,l~['Yes [] 'No Required working pressure for BOPE 1-12M; F-13M; 1~5M; 1-110M; F-II~M; Other: ~ ~.~ ' Approved~'' ~' ~''-~ ~ ~~~ " Commissioner by order of zne commission Date~¢,.~..~ Form 10-401 Rev. 12-1-85~,,) Submit in 1 .licate AFE No. 125399 PROPOSED DRILLING AND COMPLETION PROGRAM WELL 13-;51 [44-31-11-141 PBU WATER AND MI INJECTOR Install and cement 110' of 20" conductor to surface. The Drilling fluid program will consist of an 8.5 - 9.5 ppg spud mud in the 17- 1/2" hole, a 9.0 - 9.7 ppg water base mud in the 12-1/4" hole and a 8.5 ppg water base mud in the 8-1/2" hole. Drill vertical 17-1/2" casing to surface. hole to 2700'. Run and cement 13-3/8" L-80 Buttress ' A formation leak-off test will be performed 10' below the 13-3/8" shoe. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Drill vertical hole to 4500'. Kick-off and directionally drill 12-1/4" hole to the 9-5/8" casing point above the Sadlerochit Sandstone. Run 9-5/8" 47# L-80 NSCC casing to within 10' of 12-1/4" TD and cement with Class G cement around the 9-5/8" shoe. The annulus will be freeze protected by dry crude. A cement bond log will be run over the 9-5/8" casing to the 13-3/8" shoe. Directionally drill 8-1/2" hole to TD. Run open hole logs. Run 7" liner from TD to 250' inside 9-5/8" casing shoe and cement using Class G cement. Clean out to 7" float equipment. Change over to NaCI completion fluid. Test casing and lap to 3000 psi. Run cased hole logs. Run 7" tubing with a 9-5/8" packer. Set 9-5/8" packer 50' above top of liner. A mechanical integrity test will be performed on the tubing annulus and casing. A subsurface safety valve with dual control lines will be placed 100' below base of permafrost. Install and test Xmas tree. Displace tubing to diesel. Set and test packer. Tubing Size: Tailpipe Size: Fluids incidental to the drilling of the well will be pumped down the 9-5/8" x 13-3/8" annulus of the well. 7", 26# L-80, NSCC TBG 7" TAILPIPE MJS: 3-27-91 PRELIMINARY WELL PLAN WELL B-31 [44-31-11-14] PBU PROPOSED DEtrFH BKB 20" Conductor 110 Ball Valve 13-3/8" Casing Shoe 17-1/2" Open Hole 2100 2680 2700 7" 264/L-80 NSCC Tubing 9-5/8" Packer 8826 7" Tieback Assembly 8876 9-5/8" Shoe 12-1/4" Open Hole 9126 9136 WD Isolation Packer 7" 26//L-80 NSCC Liner WD Isolation Packer 7" PBTD 7" Liner Shoe 8-1/2" Open Hole 9777 9817 9817 PRELIMINARY WELL PLAN WELL: B-31 [44-31-11-14] PBU AFE NUMBER: 125399 LOCATION: Surface: 2106' SNL, 1611' Target: 4250' SNL, 1300' T.D.: ~.~0' SNL, 1272' WEL, Sec.31, T1 IN, R14E WEL, Sec.31, Tl lN, R14E WEL, Sec.31, T1 IN, R14E ESTIMATED START: 18th April 1991 OPR. DAYS TO COMPLETE: 20days (15days drilling, 5 days completion) CONTRACTOR: Nabors 18E MAX ANGLE/SECT COURSE/KOP/BUILD RATE: 29.9/S8.5E/4500/2.5 Item TVDss MD(BKB) Mud Wt. 20" CONDUCTOR 13-3/8" SHOE BASE WEST SAK FORMATION 9-5/8" SHOE TOP SAG RIVER SANDSTONE TOP SADLEROCHIT CURRENT GOC TARGET TOTAL DEPTH 110 8.5 2616 2680 9.5 6000 6182 9.0 8551 9126 9.7 8560 9136 8.5 8651 9241 8.5 8750 9355 8.5 8815 9430 8.5 9149 9817 8.5 LOGGING PROGRAM: OPen H01e - Record all logs on magnetic tape where applicable. 12-1/4" Hole: None 8-1/2" Hole: DIL/BHCS/SP/CNL/GR Cased Hole CBT/CET over 9-5/8" casing CBT/CET over 7" liner and Gyro survey subsequent to rig release MJS: 3-27-91 BOP STACK CONFI(3URATION 13 5/8", 5000 PSI WP TRIPLE RAM STACK DRILLING RISER ANNULAR PREVENTER 2" KILL LINE P l PE RAMS BLIND RAMS I· MANUAL HYDRAULIC GATE GATE DRILLING SPOOL i w , Pl PE RAMS 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE Search Radius= 200 7 DEGREE LEAD LINE For proposed well: B-31 [44-31-11-14] Location = W-E S-N TVD(SBS) Top 664056.00 5948545.00 -64.00 Bottom 664736.25 5946284.02 9149.91 --- Closest Approach Analysis --- Date: 27-MAR-91 Time: 10:27:47 Note: Ail depths in feet Below Kelly Bushing (BKB) Closest Approach WELL IDENT /PROPOSED% /NEARBY% TVD DEPART TVD DEPART A029-2005900 .'1 -2006600 A029-2031600 B-9 A029--2032100 B-10 ( A029--2033100 B-ii A029-2033200 B-12 A029-2034100 B-13 A029-2034900 B--14 A029--2077900 B-23 SUMMARY CLOSEST DISTANCE NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 0.0 0.0 0.1 0.0 74.0 3017.2 0.0 3017.5 25.1 17.8 3507.3 0.0 3507.6 122.5 55.9 3651.3 0.0 3651.8 196.0 162.5 3549 . 4 0 . 0 3549 . 6 169 . 2 312 . 7 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW Vertical Intersection /PROPOSED% /NEARBY~ TVD DEP~RT TVD DEPART VERTICAL DISTANCE The well which comes closest to the proposed well is: , A029-2032100 B-10 ( Closest approach distance = KICK OFF for this run = 17.8 feet 4500.0 feet Search Radius= 200 For proposed well: Location = Top Bottom Closest Approach Analysis --- Date: 27-MAR-91 Time: 10:27:09 COURSE LINE B-31 [44-31-11-14] W--E S--N TVD(SBS) 664056.00 5948545.00 -64.00 664455.63 5946217.98 9149.91 depths in feet Below Kelly Bushing (BKB) Note: Ail WELL IDENT Closest Approach /PROPOSED~ /NEARBY% CLOSEST TVD DEPART TVD DEPART DISTANCE A029-2005900 --1 NO COORDINATE POINTS -2006600 NO COORDINATE POINTS A0~ 2031600 ~---~ 0.0 0.0 A029-2032100 B-10 ( 3017.2 0.0 A029-2033100 B-11 3507.3 0.0 A029-2033~00 B-~2 3651.3 o.o A029-2034100 B-13 3549.4 0.0 A029-2034900 B-14 NO COORDINATE A029-2077900 8-23 NO COORDINATE WITHIN SPECIFIED SEARCH WINDOW WITHIN SPECIFIED SEARCH WINDOW 0.1 0.0 74.0 3017.5 25.1 17.8 3507.6 122.5 55.9 3651.8 196.0 162.5 3549.6 169.2 312.7 POINTS WITHIN SPECIFIED SEARCH WINDOW POINTS WITHIN SPECIFIED SEARCH WINDOW SUMMARY The well which comes closest to the proposed well is: A029-2032100 B-10 ( Closest approach distance = 17.8 feet KICK OFF for this run = 4500.0 feet Vertical /PROPOSED~ TVD DEPART ; Intersection /NEARBY% TVD DEPART VERTICAL DISTANCE MUD WEIGHT CALCULATIONS WELL ]~-31 (44-31-11-14~ Mud Wt. (8-1/2" Hole): 8.5ppg. P Sag River: P Sadlerochit: P Top Sadlerochit: 3591 psi. 3675 psi. at 8800' TVDSS 3648 psi. OB Sag River: OB Top Sadlerochit: Current GOC: 220 psi. 205 psi. 8814' TVDBKB 9-5/8" Casing Pt. Top Sag River Top Sadlerochit 8615' TVDBKB 8624' TVDBKB 8715' TVDBKB Cement Calculations 13-3/8" CASING Measured Depth: Basis: Total Cement Vol: Lead Slurry Vol: Tail Slurry Vol: 2680' 2. X Annular volume 3723. (cuft) 2778 (cu ft) 1410Sx Permafrost E @ 1.97 Cu ft/Sk 945 (cu ft) 1015 Sx Permafrost @ 0.93 Cu ft/Sk ~-5/8"CASING Measured Depth: 9126' Basis: 90% Annular Volume to 13-3/8" + 50 cu ft Total Cement Vol: 1866 (cu ft) Lead Slurry Vol: 1576 (cuft) 835 Sx G+8% @ 1.89 Cu ft/Sk Tail Slurry Vol: 290(cu ft) 250 Sx (3 Neat @ 1.15 Cu ft/Sk 7" LINER Measured Depth: 8876' (Hanger) - 9817' (Shoe) Basis: 1.5 X Annular volume to 9-5/8" shoe + 150 cuft Total Cement Vol: 240 (cu ft) 210 Sx Neat G @ 1.18 Cu ft/Sk MJS: 3-27-91 ["iUD ~ILL TAAJK 3a ~. 2~O V~L~/H E rAk/g lOC) I~LUHE T,l~g TRIP TANK .,~A r',J D ;' D~'GASSER TAI',IK IqO BSL TYF~ HUO - Choke Manifold TO Srl~JD I~ - Poor Boy Degasser · - Brandt VacuumvType Degasser - Brand t Dual Tandem Shale Shaker -'P~oneer Mud Cleaners - Pioneer MKI Centrifuge D DISTRIWjTION DITC / · '! / I ' /' / 1 - RecOrding drilling fluid, pit 'level indicator with both visual and audio warning devices at driller's con~ole ' - 1 - Trip Tank (75 BBL.) 1 - Drilling fluid flow sensor with readoub at driller's console 11 - 5 Hp Agitators ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE. Z2c_ 2. [2 thru 8] 3. 4. '[~J ~hru 1 [10 & 13] [14 thru 22] (5) BOPE [23 thru 28] (6) Other ~ ~/~/~/ [29 thru 3i]' (6) Addl Se 6. 7. 8. 1 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Company 23. 24. 25. 26. 27. 28. 29. 30. 31. Is pemit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-daY"wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nt~nber appropriate .......................................... Does well have a unique name & n~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ..... . ........................ Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~O~psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Lease & Well ~ ~ YES NO 32. Additional requirements ............................................. ~. REMARKS geol ogy' DWJ _~ RPC ./~ eng i neer i ng,: MTM_~ LCS~_~_ BEW.~ RAD' dH~w~-f INITIAL GLO1 uNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' rev 03/29/91 6.011 0 --I -rz ,--,0 (.,n --t Well Histo,ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well HiStory file and to simplify finding information, information, of this nature is accUmulated at the end of the file under APPENDIXi ,. No special'effort has been made to chronologically organize this category of information. PROGRAM: LISCAN REVISION: 5.2 PART NUMBER: W5790-MICRO Start of execution: Tue 14 MAY 91 8:56a **** REEL HEADER **** LIS 91/ 5/14 AWS 01 **** TAPE HEADER **** LIS 911 5/14 O1 FILE # 1 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : BP EXPLORATION (ALASKA), : S - 31 ((44-31-11-14) : PRUDHOE BAY : NORTH SLOPE : ALASKA * COMMENT RECORD * API NO. 50-029-22152 LOG DATE: 5/9/91 FILE 1 = MAIN PASS: DIFL/BHC-AL/GR (9050 - 9860 FT.) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 15 CURVES : NAME CODE SAMPLE# UNIT 1 AC 68 1 US/F 2 CHT 68 1 LBF 3 CILD 68 1 MMHO 4 CLSN 68 1 CPS 5 CN 68 1 % 6 CNC 68 1 % 7 CSSN 68 1 CPS 8 GR 68 1 API 9 RFOC 68 1 OHMM 10 RILD 68 1 OH~M 11 RILM 68 1 OHMM 12 SP 68 1 MV 13 SPD 68 1 F/MN 14 TEMP 68 1 DEGF 15 TTEN 68 1 LBF BYTES 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 * DATA RECORD DEPTH CN RILD TTEN 9860.000 -999.2500 -999.2500 -999.2500 9810.000 0.0000000E+00 2.913805 4961.984 9760.000 19.66087 2.711762 4911.094 9710.000 18.85181 2.013114 4781.949 9660.000 21.68277 3.235893 4774.770 9610.000 15.06277 5.268495 4796.898 9560.000 12.12482 5.281722 (TYPE# 0 ) AC CNC RILM -999.2500 -999.2500 -999.2500 76.16248 0.0000000E+00 3.487676 89.71858 24.71648 2.820090 88.68973 23.88187 2.322808 91.30737 26.76031 3.750864 83.23547 19.97545 6.950997 81.49664 16.94899 6.882872 966 BYTES * CHT CSSN SP -999.2500 -999.2500 -999.2500 1192.813 0.0000000E+00 -44.55249 1148.407 212.9780 -40.84828 1072.440 211.8726 -46.31551 1056.327 217.9059 -36.82129 1028.599 237.7023 -46.33464 1019.838 261.7280 -30.34526 CILD GR SPD -999.2500 -999.2500 -999.2500 343.1938 0.0000000E+00 26.99730 368.7639 24.78674 26.99730 496.7429 21.19214 26.99730 309.0337 15.72598 26.99730 189.8075 18.61067 26.99730 189.3322 25.51086 26.99730 CLSN RFOC TEMP -999.2500 -999.2500 -999.2500 -60.00000 9.572229 173.9070 116.5473 8.500830 173.1654 118.3077 9.742647 172.0722 113. 7150 17.29301 172. 2579 147.4848 11.35972 171.3828 178.9469 14.92281 169.8705 4731.223 9510.000 82.53041 1048.007 74.69286 130.7313 18.13725 23.14490 229.8397 29.59569 20.21230 13.38816 13.44949 -10.62882 26.34241 168.7773 4764.777 9460.000 98.45969 1016.712 55.20793 97.95541 24.82498 29.86089 200.5872 27.08038 26.78343 18.11334 19.73026 -8.659889 26.99730 167.4357 4675.848 9410.000 96.71475 1022.191 30.33478 104.2712 22.86456 27.92641 205.0615 19.89653 37.54367 32.96547 29.74220 -35.42024 26.99730 167.0335 4658.121 9360.000 92.37534 1083.844 27.74570 100.9125 23.66348 28.71474 201.8288 19.20625 47.55177 36.04163 37.91469 -27.88708 26.99730 165.2698 4791.402 9310.000 98.02831 1180.276 42.37401 125.0101 17.99785 23.00113 218.9758 26.81958 33.18077 23.59937 26.81088 -26.62170 26.99730 164.5164 4858.145 9260.000 67.77647 1257.320 15.00486 267.7039 7.097136 11.39771 316.1096 100.5314 155.5399 66.64507 120.2201 36.96725 26.99730 163.0503 4905.324 9210.000 61.13995 1297.955 42.34714 220.2644 11.55585 16.36313 315.5400 73.87498 26.69070 23.61435 30.53430 14.00966 16.99831 160.3867 4866.738 9160.000 57.05917 1300.622 150.9480 32.81680 73.20650 76.33607 110.7855 67.82234 0.4525126 6.624798 10000.00 -89.57802 19.99800 158.2058 4826.113 9110.000 79.00772 500.0000 0.0000000E+00 63.35083 66.93958 113.5230 50.84021 0.2000000 0.2000000 -83.26126 0.0000000E+00 4500.000 9060.000 50.00000 500.0000 0.0000000E+00 80.69453 83.47548 105.3895 50.46352 0.2000000 0.2000000 -80.00000 0.0000000E+00 4500.000 35.68671 0.2000000 100.0000 30.04250 0.2000000 100.0000 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 109 9860.00 ENDING TAPE DEPTH = 9050.00 **** REEL HEADER **** LIS 91/ 5/14 AWS 01 **** TAPE HEADER **** LIS 91/ 5/14 01 FILE # 2 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : BP EXPLORATION (ALASKA), : S- 31 ((44-31-11-14) : PRUDHOE BAY : NORTH SLOPE : ALASKA * COMMENT RECORD * FILE 2 = REPEAT SECTION: DIFL/BHC-AL/GR (9050 - 9860 FT.) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 15 CURVES : NAME CODE SAMPLE# UNIT BYTES 1 AC 68 1 US/F 4 2 CHT 68 1 LBF 4 3 CILD 68 1 MMHO 4 4 CLSN 68 1 CPS 4 5 CN 68 1 % '4 6 CNC 68 1 % 4 7 CSSN 68 1 CPS 4 8 GR 68 1 API 4 9 RFOC 68 1 OHMM 4 10 RILD 11 RILM 12 SP 13 SPD 14 TEMP 15 TTEN 68 1 68 1 68 1 68 1 68 1 68 1 OHMM 4 OHMM 4 MV 4 F/MN 4 DEGF 4 LBF 4 * DATA RECORD DEPTH CN RILD TTEN 9860.000 -999.2500 -999.2500 -999.2500 9810.000 0.0000000E+00 2.933659 4901.375 9760.000 21.30186 2.707147 4806.523 9710.000 23.67860 2.027056 4728.309 9660.000 22.71443 3.078343 4746.961 9610.000 15.44884 5.646831 4729.129 9560.000 12.33709 5.758395 4703.574 9510.000 16.36142 13.00052 4767. 098 9460.000 22.58076 19.70058 (TYPE# 0 ) AC CNC RILM -999.2500 -999.2500 -999.2500 76.92152 0.0000000E+00 3.495021 90.32495 26.38449 2.804988 88.43074 28.72966 2.330733 91.38043 27.77827 3.499978 83.66055 20.37329 7.826258 80.14482 17.16759 7.123190 81.99057 21.31390 12.93157 99.23579 27.64638 21.13826 966 BYTES * CHT CSSN SP -999.2500 -999.2500 -999.2500 1043.010 0.0000000E+00 -49.28978 994.3508 210.6849 -46.42651 927.7039 210.9331 -47.85086 978.3501 211.7913 -40.78725 938.3745 231.7985 -46.58502 928.2153 260.5925 -35.56015 977.5034 223.8647 -16.64951 958.2415 196.9036 -17.75339 CILD GR SPD -999.2500 -999.2500 -999.2500 340.8713 0.0000000E+00 35.03221 369.3926 33.02623 26.99730 493.3264 16.16930 27.99721 324.8501 15.70536 27.99721 177.0905 15.98625 27.59100 173.6595 22.66116 27.43921 76.92001 34.68904 27.99721 50.75992 26.23528 27.99721 CLSN RFOC TEMP -999.2500 -999.2500 -999.2500 0.0000000E+00 9.694702 166.6552 110.9003 8.334776 166.2876 105.4315 9.741991 165.7762 108.0414 16.30681 166.3480 142.1551 12.77249 165.9651 176.8277 16.07153 164.6078 133.6.770 18.96623 163.2162 100.7374 31.50438 162.0352 4633.422 9410.000 96.39529 964.6343 30.14836 105.3484 21.91347 26.98795 202.9187 18.52838 38.78667 33.16930 30.48468 -39.91396 27.99721 161.5440 4627.883 9360.000 92.47026 1060.148 28.56355 102.8146 22.86893 27.93071 202.2157 17.37904 47.65950 35.00964 36.45~19 -27.67967 27.99721 160.5537 4750.992 9310.000 97.74588 1117.293 41.84250 125.7398 17.70685 22.70105 218.5555 27.59703 33.27040 23.89914 26.02875 -23.65483 27.99721 160.1942 4797.453 9260.000 66.66449 1206.162 12.62580 275.1040 7.090556 11.39032 324.7388 98.91171 194.5639 79.20291 151.5732 25.76959 27.99721 159.3342 4935.637 9210.000 61.06874 1195.085 42.78564 234.5181 10.86002 15.63028 327.2073 71.97160 30.56989 23.37233 31.38414 -1.951414 21.55591 155.8185 4840.094 9160.000 66.20969 1202.983 148.2971 36.70490 57.28876 61.16011 111.8419 70.27505 0.4587153 6.743218 10000.00 -116.2424 15.99840 153.4843 4779.762 9110.000 55.92798 500.0000 0.0000000E+00 77.77295 80.68990 112.8986 52.20251 0.2000000 0.2000000 -80.00000 0.0000000E+00 4500.000 32.64940 0.2000000 100.0000 9060.000 50.00000 500.0000 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 0.0000000E+00 51.84953 0.2000000 0.2000000 0.2000000 -80.00000 0.0000000E+00 100.0000 4500.000 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 109 9860.00 ENDING TAPE DEPTH = 9050.00 **** REEL HEADER **** LIS 91/ 5/14 AWS 01 **** TAPE HEADER **** LIS 91/ 5/14 01 FILE # 3 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : BP EXPLORATION (ALASKA), : B- 31 ((44-31-11-14) : PRUDHOE BAY : NORTH SLOPE : ALASKA * COMMENT RECORD * FILE 3 = CASED HOLE CN-GR: (7920 - 9270 FT.) * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 10 CURVES : NAME 1 GR 68 2 CHT 68 3 CLSN 68 4 SP 68 5 SPD 68 6 CN 68 7 CNC 68 8 TEMP 68 9 TTEN 68 10 CSSN 68 CODE SAMPLE# UNIT BYTES 1 API 4 1 LBF 4 1 CPS 4 1 MV 4 1 F/MN 4 1 % 4 1 % 4 1 DEGF 4 1 LBF 4 1 CPS 4 * DATA RECORD DEPTH SPD CSSN (TYPE# 0) 1018 BYTES *' GR CHT CN CNC CLSN TEMP SP TTEN 9270.000 -999.2500 -999.2500 9220.000 42.65071 0.0000000E+00 9170.000 42.10500 128.0784 9120.000 42.65071 108.0129 9070.000 41.99580 111.1186 9020.000 41.99580 112.5612 8970.000 42.10500 142.0639 8920.000 42.10500 121.7276 8870.000 41.99580 127.9104 8820.000 41.99580 124.0938 8770.000 42.75990 143.1066 8720.000 42.10500 125.9896 8670.000 41.99580 121.6751 8620.000 42.23160 122.2004 8570.000 43.88641 116.0488 -999.2500 -999.2500 0.0000000E+00 0.0000000E+00 140.3166 38.43619 50.75389 75.56917 64.30522 69.65620 57.08553 56.64265 47.35803 51.34865 69.79].81 62.36061 68.27902 64.35596 67.42619 70.78914 52.60793 47.17647 69.72585 68.13329 61.96571 68.04997 68.42326 67.08191 62.81854 68.07372 -999.2500 -999.2500 1395.897 0.0000000E+00 1335.779 36.00208 1309.249 67.72270 1317.232 62.40579 1320.589 51.22629 1299.825 46.82338 1299.758 56.41383 1291.149 58.08194 1298.564 63.66701 1289.981 43.33714 1287.208 61.15631 1294.218 60.86327 1281.169 60.17787 1296.780 61.29141 -999.2500 -999.2500 -60.00000 158.4121 50.28581 157.8857 31.77440 156.4522 34.22870 155.7508 37.37160 154.9730 47.49901 153.8346 38.15880 153.0103 37.30760 152.0882 35.58521 151.4319 50.31430 150. 1280 40.41400 149.3079 38.91980 148.0694 39.73360 147.1320 36.41521 146.1605 -999.2500 -999.2500 26.19438 4847.762 21.63501 4816.668 -41.97185 4797.926 -33.38864 4722.004 -28.49219 4722.527 -16.24910 4689.031 -16.75223 4659.129 -15.57329 4639.945 -27.31024 4566.371 -37.74925 4565.824 -20.34286 4542.648 -27.67186 4493.609 -30.15649 4445.090 -11.37124 4439.570 8520.000 59.43413 42.99571 69.87132 113.6603 8470.000 61.19116 43.88641 67.62248 116.5118 8420.000 66.42316 43.34070 71.05356 124.2118 8370.000 61.41783 42.99571 72.64732 113.2294 8320.000 53.00142 43.65060 58.54259 115.3492 8270.000 60.68079 42.99571 64.46680 111.2588 8220.000 47.60287 43.88641 51.91524 121.7195 8170.000 71.89728 43.10490 64.48798 112.8221 8120.000 87.10463 42.99571 83°80348 107.2608 8070.000 124.9434 43.65060 73.53912 109.5207 8020.000 100.1660 42.99571 66.08337 115.4516 7970.000 69.61272 0.0000000E+00 61.30055 118.2744 7920.000 -999.2500 -999.2500 -999.2500 -999.2500 1315.406 34.23630 -12.19035 62.79355 145.1508 4404.594 1339.514 38.13391 -8.362209 60.80318 144.2387 4345.719 1334.909 38.35451 -3.504634 63.73744 142.7607 4314.730 1343. 745 36. 15871 -9. 640671 64 . 79305 141. 3514 4304 . 102 1376.485 37.97990 -9.852222 53.03366 140.8472 4275.551 1388.057 34.67311 -6.759470 58.06119 139.8482 4256.344 1398.238 44.34460 -6.724213 47.20435 138.9073 4232.340 1387o301 33.81790 -7.633211 58.49219 137.5929 4190.848 1420.696 29.88710 -9.643246 74.31622 137.0819 4191.980 1461.468 34.77431 -10.60394 65.43596 136.4945 4181.531 1490.440 35.17540 -9.346321 60.23419 136.2160 4167.516 500.0000 36.11591 -80.00000 55.73329 100.0000 4500.000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 118 9270.00 ENDING TAPE DEPTH = 7920.00 **** TAPE TRAILER **** LIS 9~/ 5/14 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 358 **** REEL TRAILER **** LIS 91/ 5/14 AWS 01 TOTAL RECORDS IN THIS LOGICAL REEL : 359 TOTAL RECORDS IN THIS PHYSICAL REEL: 359 End of execution: Tue 14 MAY 91 8:57a Elapsed execution time = 55.75 seconds. SYSTEM RETURN CODE = 0
