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Home My WebLink About192-089Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:192-089 6.50-029-20586-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10305 10262 9097 9672 10165 none 8652 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 32 - 110 32 - 110 Surface 2611 13-3/8" 31 - 2642 31 - 2642 4930 2670 Intermediate 7345 9-5/8" 30 - 7345 30 - 6887 6870 4760 Production 60' 9-5/8" 7345 - 7405 6887 - 6933 8150 5080 Perforation Depth: Measured depth: 9936 - 10154 feet True vertical depth:8849 - 9014 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 29 - 9740 29 - 8703 9672 8652Packers and SSSV (type, measured and true vertical depth) 4-1/2" Otis MHR Liner 3128 7" 7177 - 10305 6758 - 9130 7240 5410 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 22612191244165 11330 1224 0 283 235 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: David Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907)564 - 4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9130 Sundry Number or N/A if C.O. Exempt: 320-394 4-1/2" TRDP-4A (locked out) No SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028330 PBU 12-10A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Installed kinley orifice checks By Samantha Carlisle at 10:17 am, Apr 15, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.14 11:43:06 -08'00' Bo York SFD 4/19/2021DSR-4/15/21 RBDMS HEW 4/15/2021 MGR01JULY2021 ACTIVITYDATE SUMMARY 3/20/2021 T/I/O=1950/450/100 Temp=S/I (Assist SL with load and test) Pumped 2 bbls 60/40 and 181 bbls crude down the tbg to load. CMIT-TxIA PASSED to 2705 psi. Max applied pressure=2750 psi. Target pressure=2500 psi. Pumped 15.1 bbls of crude down the tbg and IA to reach test pressure. 1st 15 min T/IA lost 10/30 psi. 2nd 15 min T/IA lost 5/15 psi. Total loss of 15/45 psi in 30 min test. MIT-IA to PASSED to 2725 psi. Max applied pressure=2750 psi. Target pressure 2500 psi. 1st 15 min IA lost 0 psi. 2nd 15 min IA lost 25 psi. 3rd 15 min IA lost 0 psi. Total loss of 25 psi in 30 min test. FWHP=260/350/125 Slickline still on well upon departure. 3/20/2021 ***CONTINUED FROM 3/19/21 WSR*** (Gas lift for rate) THUNDERBIRD LOADED TUBING W/ 181 BBLS OF CRUDE. SET 4-1/2" XX PLUG IN X-NIPPLE AT 9,627' SLM / 9,653' MD. THUNDERBIRD PERFORMED SUCCESSFUL CMIT-T x IA TO 2705 PSI. THUNDERBIRD PERFORMED SUCCESSFUL MIT-IA TO 2725 PSI. PULL RK-DGLV FROM ST #2 (5,290' MD). PUSH FLUID OUT OF IA USING LIFT GAS TAKING RETURNS OUT FLOWLINE FOR 2 HRS. ***LDFN, WELL S/I & SECURED, CONTINUED ON 3/21/21 WSR*** 3/21/2021 ***CONTINUED FROM 3/20/21 WSR*** (Gas lift for rate) FOUND FLUID LEVEL IN TUBING AT 5,130' SLM W/ 4-1/2" GS. SET RK-DGLV AT ST #2 (5,290' MD). SET 4-1/2" SLIP STOP CATCHER SUB AT 6,673' MD (Piston for Kinley puncher 2' from bottom). RAN 4-1/2" KINLEY PUNCHER & SET 16/64" CHECK INSERT AT 6,671' MD. MOVE 4-1/2" SLIP STOP CATCHER FROM 6,673' MD TO 6,662' MD. RAN 4-1/2" KINLEY PUNCHER & SET 16/64" CHECK INSERT AT 6,660' MD. PULL 4-1/2" SLIP STOP CATCHER SUB FROM 6,638' SLM / 6,662' MD. ***LDFN, WELL S/I & SECURED, CONTINUED ON 3/22/21 WSR*** 3/22/2021 ***CONTINUED FROM 3/21/21 WSR*** (Gas lift for rate) EQUALIZE & PULL 4-1/2" XX PLUG BODY FROM 9,627' SLM / 9,653' MD. PULL RK-DGLV FROM ST #2 (5,290' MD) & ST #1 (3,341' MD). SET RK-LGLV AT ST #1 (3,341' MD) & ST #2 (5,290' MD). PULL EMPTY 4-1/2" WHIDDON CATCHER SUB FROM 9,703' SLM / 9,727' MD. ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** Daily Report of Well Operations PBU 12-10A Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/23/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL GPB 12-10A (PTD 192-089) RCBL Radial Cement Bond Log 09/13/2020 Please include current contact information if different from above. Received by the AOGCC 10/23/2020 Abby Bell 10/23/2020 PTD: 1920890 E-Set: 34126 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:192-089 6.API Number:50-029-20586-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028331 Property Designation (Lease Number):10. 8. PBU 12-10a 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Tubing punch Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 10305 Effective Depth MD: 13Cr80 11. 10/15/2020 Commission Representative: 15. Suspended Contact Name: David Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9130 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool No Packer No SSSV Installed Date: Liner 3128 7" 7177 - 10305 6758 - 9130 7240 5410 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 31 - 2642 31 - 2642 14. Estimated Date for Commencing Operations: BOP Sketch 32 - 110 Structural 6870 Proposal Summary 13. Well Class after proposed work: No Packer 9936 - 10154 8849 - 9014 4-1/2" 12.6# 13Cr80 29 - 9740 Production 10262 9097 32 - 110 13-3/8" 9-5/8" Contact Phone:(907) 564-4672 Date: 9/23/2020 4760 78 20"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2611 4930 Intermediate 7345 7345 6887 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. none none By Samantha Carlisle at 1:29 pm, Sep 24, 2020 320-394 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.09.24 10:34:30 -08'00' Bo York ADL0028330 DLB X DLB 09/24/2020 DSR-9/24/2020 2338 10-404 MGR26SEP2020 Yeion Required? C 10/6/2020 dts 10/6/2020 JLC 10/6/2020 RBDMS HEW 10/29/2020 Well Name:12-10a API Number:500292058601 Current Status:online Rig:SL Estimated Start Date:October 2020 Estimated Duration:1 Day Reg.Approval Req’std?Yes Date Reg. Approval Rec’vd: First Call Engineer:David Bjork 907 440 0331 Second Call Engineer:Ryan Thompson 907 301 1240 Current Bottom Hole Pressure:3218 psi @ 8800’ TVD SBHP Survey 06/22/2018 Maximum Expected BHP:3218 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2338 psi Gas Column Gradient (0.1 psi/ft) Max Inc:42° @ 7,877’ Max DLS:4.2°/100 ft @ 5900’ MD Brief Well Summary 12-10a developed a production liner top leak. It was repaired in 2012 with an IA cement job. The lower GLM was covered with cement. A CBL confirms the cement top is at 6,795’. This program is to install a TBG punch with orifice check valve, to allow deeper gas lift. A CBL log was ran 9/13/20 to confirm the calculated cement top. Objective: x SL Kinley TBG punch with two GL orifice x POP well with GL Sundry Procedure (Approval Required to Proceed: Slickline and or Eline 1. MIRU SL 2. Pressure test to 300 psi low and 2,500 psi high 3. RIH with Kinley punch tool and install (2) 16/64’’ check valve inserts at 6,660’ and 6,670’. 4. Set new GL design in upper two stations. 5. POP with GL 0.1 AOGCC will require an MIT-IC to 2500 psi. Charted 30 minute test. f • w\��j,' THE STATE Alaska Oil and Gas ofALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue O� Q+ Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 John McMullen Engineering Team Leader n BP Exploration (Alaska), Inc. I �v P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12 -10A Sundry Number: 313 -076 Dear Mr. McMullen: OR 11 20 13 SC ANNED Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this da y of February, 2013. Encl. STATE OF ALASKA � 4 " ". CEIVED .. , I , . ALAI OIL AND GAS CONSERVATION COMMS ION ft!' FEB 13 1 APPLICATION FOR SUNDRY APPROVAL PS Z 11 1 ! Z,. 20 AAC 25.280 AOGCC 1. Type of Request: ❑ Abandon !_ Plug for Redrill • El Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. 192 - 089 ' ❑ Exploratory 0 Stratigraphic 3. Address: 6. API Numbe ® Development ❑ Service P.O. Box 196612, Anchorage, Alaska 99519 -6612 50. 029 - 20586 - 01 - 00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? pBU 12 -10A Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior 10. Field / Pool(s): ADL 028330 Prudhoe Bay / Prudhoe Bay • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft)• Effective Depth TVD (ft): Plugs (measured): Junk (measured) 10305' , 9130' . 10262' 9097' None 10165' Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 2642' _ 13 -3/8" 2642' 2642' 4930 2670 Intermediate 7345' 9 -5/8" 7345' 6887' 6870 4760 Production Liner 3128' 7" 7177' - 10305' 6758' - 9130' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9936' - 10154' 8849' - 9014' 4 -1/2 ", 12.6# 13Cr80 9740' Packers and SSSV Type: 7" x 4 -1/2" Otis MHR Packer Packers and SSSV 9672' / 8652' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation February 20, 2013 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brad Gorham, 564 -4649 Printed Name: John r .ie Title: Engineering Team Leader Email: Bradley.Gorham @bp.com Signature: / / � ' `�. Phone: 564 - 4711 Date: 2 . s •. f Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 --(�] („ r v v w ❑ Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: B G p 1 f 7 3 SO O p 5 t- RBDMS MAR 01 Spacing Exception Required? ❑ Yes ❑ No Subsequent Form Required: / r — 4 o -7 - I APPROVED BY T Approved By: ri I COMMISSIONER THE COMMISSION Date: Z 2g — L3 Form 10-403 R.: - IP 1 1 ( red application is valid for 12 months from the date of approval Submit In Duplicate VLF 2/ 4* 27_1.5 ID • To: Alaska Oil & Gas Conservation Commission From: Brad Gorham b p CTD Engineer Date: February 12, 2013 Re: 12 -10A Sundry Approval History of 12 -10A: 12 -10 was drilled in 1981 and produced about 10 years before then being sidetracked. 12 -10A was originally completed in 1992 as a waterflood producer with chrome tubulars. The recommended best utilization of this wellbore is a CTD sidetrack. Reason for Sidetrack: Given the low oil rates and high water production a CTD sidetrack is . proposed to access reserves. Proposed Plan for 12 -10B: The proposed plan for 12-10B is to drill a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig on or around April 15, 2013. The existing perforations will be isolated by a cement downsqueeze after setting the whipstock, as well as the primary cement job. The sidetrack, 12-10B, will exit the existing 7" liner and kick off in Zone 4 staying in Zone 4 throughout the wells entirety. The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. Pre-Rig Work: (scheduled to begin February 20, 2013) T COh cvi . i , ��tr we i ifodv�� g ( g Y f PSS y444 l 5 60/ W i'i t U/L 1. n e«£ 55 of l 49 laf'( etGf S Dummy GLV s � . 2. F Test MIT -IA to 3,000 psi (passed to 3,000 psi — 10/13/12 S "Cider/k4 3. W Test PPPOT -T to 5,000 psi 3.40.V lecd ; r U „ eet ° 4. E Mill XN profile at 9,727' MD to 3.80” S � 014 5. S Dummy WS drift to 10,090' MD ►rP l� 6. E Set 4 -1/2" x 7" Thru Tubing WS at 9,990' MD (330° ROHS) - Ike P ; % 7. C Lay in 29 bbls Cmt and squeeze perfs above and below the WS 8. C Clean out down to 9,980' MD (10' above WS) 1' A 9. V PT MV, SV, WV 10. 0 Bleed gas lift and production flowlines down to zero and blind flange RID t q2` $ 11. 0 Remove wellhouse, level pad 5 vncivy 3 l 3 "D 12. V Set TWC. — 24 hrs prior to rig arrival. Rig Work: (scheduled to begin on April 15, 2013) N� � /1-06e- j Zy h 1. MIRU and test BOPE to 250 psi low and 3500 psi high. a vat �i c 2. Mill 3.8" window at 9,990' and 10'of rathole. Swap the well to Power -Vis. 3. Drill Build: 4. 25" OH, 746' (25 deg/100 planned) with resistivity 4. Drill Lateral: 4.25" OH, 1,405' (12 deg /100 planned) with resistivity 5. Run Triple Combo Open Hole Logs 6. Run 3 -1/4" L -80 x 2 -7/8" Cr liner leaving TOL at 9,710' MD. 7. Pump primary cement leaving TOC at 9,710', 30 bbls of 15.8 ppg liner cmt planned 8. Cleanout liner and MCNL /GR/CCL log 9. Test liner la�to 2400 psi. 10. Perforate liner per asset instructions (1,200') A/c w P 7 11. Freeze protect well to 2,500' TVD 12. Set BPV, RDMO • • Post -Rig Work: 1. Re- install wellhouse and FL's. 2. Generic GLV's Brad Gorham CTD Engineer 564 -4649 CC: Well File Sondra Stewman/Joseph Lastufka TREE= GRAY GEN 4 WR_LHEAD= GRAY • .4, NOTES: *'* CHROME TUBING & LNR *** ACTUATOR = OTIS 1 2-1 OA KB. ELEV = 71' BE REV = KOP = 4400' Max Angle = 42° @ 7877' Datum MD = 9965' 2050' — 14 -1/2" CAMCO TROP SSSV NP, D = 3.813" Datum TVD = 8800' SS TRDP --1A LOCKED OUT (04104/12) 13 -3/8" CSG, 72#, N-80, D = 12.347° H 2642' I-- GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3341 3340 2 /MGM DMY RK 0 10/18/12 Minimum ID = 3.72 @ 9727' 2 5290 5222 32 MMGM DMY RK 0 10/18112 4 -1/2" OTIS XN NIPPLE 3 7159 6744 40 MMGM DMY RK 0 10/18/12 Vt. 010 4, 6833' H ESTIMATED TOP OF CEMENT (10/08/12) I TOP OF 7" LNR 7177' F , 1414 ■i ■ ;1% 9 9 -518" SECTION WI\DOW 7345' - 7405' 9-5/8" CSG, 47 #, L- 80/S0O -95, ID = 8.681" I 7405' ∎ 4 I +! i 1 fit # 441 ` 9653' H4-1/2" PARKER SWS NP, ID = 3.813" I I TBG PUNCH, 4 SPF (09/29/12) -H 9645' - 9649' I 4ititttt ttttt ∎tttttttt4, 1; L 9672' Hr X4-1/2" OTIS 1111 FKR, D = 3.875" 0tttt 11 tttttt� • i t i t i t t t i t t � : 9706' I-I4 -1 /2" PARKER SWS NP, 13= 3.813" 4tttttt •■•••••• �t ■ • 9727' I--I4-1/2" 0'11S XN NP, D = 3.725" 1 t t• A • 1 , 1 , 1 �1 1 I9 -5/8" FES BRDGE PLUG H 7605' 9740' H 4-1/2" 1NLEG I 9729' — I ELK) TT LOGGED 11 /16/92 4-1/2" TBG, 12.6#, 13 CR .0152 bpf, D = 3.958 " —I 9740' ` PERFORATION SUMMARY 10165' — FISH -CUP - MLLE) REF LOG: BRCS ON 10/28/92 ` PUSHED TO BTM & ANGLE AT TOP PEFF: 42° @9936' (10\09 \12) Note: Refer to Production DB for historical pert data ` SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9936 -9958 0 10/18/93 3-3/8" 4 10070 -10090 0 11/15/92 3-3/8" 4 10070 -10090 0 04/08/01 3-3/8" 4 10100 -10120 0 04/08/01 3-3/8" 6 10122 -10126 0 07/15/94 3-3/8" 4 10125 -10135 0 04/08/01 3-3/8" 6 10140 -10154 0 07/15/94 FBTD 10262' .,,,11` N4s4 4 4,.. 7" LW, 26#, 13 -CR S0, .0383 bpf, ID= 6.276" H 10305' I ► DATE REV BY COMMENTS DATE REV BY CONVENTS PRUDHOE BAY MT 11/01/92 ORIGINAL COMPLETION 09/21/12 MSS/A13 GLV CIO (09/18/12) WELL: 12 -10A 11/01/92 LAST WORKOV9 10/02/12 SET /JMD COMP PLUG & TBG PUI CH (09/29 /12) PE2tAT No: 9920890 05/31/06 DTM W LLHEAD CORRECTION 10/14/12 TTWPJC CEN1 TT/ MLL RJSH UP BTM (10/9112) AR No: 50- 029 - 20586 -01 08/13/06 DAV /PJC SSSV CORRECTION 11/10/12 BSE/ PJC GLV CIO (10/18/12) & FISH CORRECTION SEC 18, TON, R15E 768' FSL & 733' FE_ 04/05/12 GJF /JMD SSSV LOCKED OUT (4/4/12) 04/18/12 PJC PERFCORRECTIONS I) BP Exploration (Alaska) TREE= GRAY GEN 4 WE LLHEAD= GRAY • • 12-10B S f NOTES: "'CHROME TUBING &LNR"** VVE ACTUATOR= OTIS CTD Planned Sidetrack KB. ELEV = 71' BF. ELEV= KOP= 4400' Max Angle = 42° @ 7877' Datum M3= 9965' 2050' H 4 - /2" CAMCO TRDP SSSV NP, D = 3.813" Datum TVD = 8800' SS O TRDP -1A LOCKED OUT (04/04/12) 13 -3/8" CSG, 72#, N-80, D = 12.347" —I 2642' GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.725" 9727 1 MMGM DMY RK 0 10/18/12 2 5290 3341 5222 3340 32 2 MMGM DMY RK 0 10/18/12 4 -1/2" OTIS XN NIPPLE pir 3 7159 6744 40 MMGM DMY RK 0 10/18/12 6833' - ESTIMATED TOP OF CEMENT (10/08/12) TOP OF 7" LNR H 7177' iii 0 9 -5/8" SECTION WINDOW 7345 - 7405' 9-5/8" CSG, 47 #, L- 80/S00 -95, D = 8_681" — 7405' o 1 / ri 0.4•4 ! ` 0 1 1A6 ` 965T H4 - 1/2" PARKER SWS NP D , = 3.813" TBG PUNCH, 4 SPF (09/29/12) H 9645' - 9649'1 1 11111 11111 9672' - 7" X 4-1/2" OTIS NI-112 - F+(R, = 3.875" 1 1 1 1 1 1 4 C .; 111111 % : 9706' —14-1/2" PARKER SWS NP, D = 3.813" ■ )1 - -9710' TOO FtC �1111111111111111�� 972T H4-1/2" OTIS XN NP , 13= 3.725" ►111111111 Mill to 3.80" • 1 •1 1 1 1 1 1 • 1 1 1 1 1 1 1 1 • 1 • 1/11///1/11 41/11.1.111 111111111 .1.1.1. 1.1.1.1.1.1.1.11 19-5/8' I-ES BRIDGE PLUG — 7605' 9740' — 14 -1/2" WLEG l 42° I 9729' H ELMD TT LOGGED 11/16/92 WS Orient 330' ROHS TOWS at 9,990' MD • 2- 7/8 "13Cr x 3 -1/4" L -80 xo - 11,800' MD( or as deep as possible) • ' ' %4 - 10165' — FISH -CBP- MILLED TD - 12,259' PUSHEDTOBTM& (10109 \12) PERFORATION SUMMARY - REF LOG: BHCS ON 10/28/92 ` ANGLE AT TOP PERF: 42° @ 9936' Note: Refer to Production DB for historical pert data SIZE SFF INTERVAL Opn /Sqz DATE 3-3/8" 4 9936 -9958 0 10/18/93 3-3/8" 4 10070 -10090 0 11/15/92 3-3/8" 4 10070 -10090 0 04/08/01 � 44k 3-3/8" 4 10100-10120 0 04/08/01 X1 3-3/8" 6 10122 -10126 0 07/15/94 �� -] 10262' ` : ∎4 ∎4 %i N;\;44 • 3-3/8" 4 10125 -10135 0 04/08/01 `►► 3-3/8" 6 10140 -10154 0 07/15/94 7" LNR, 26#, 13 - 80, .0383 bpf, D = 6276" —I 10305' DATE REV BY COMMENTS DATE REV BY C OMNEJTS PRUDHOE BAY UNIT 11/01/92 ORIGINAL COMPLETION 09/21/12 MSS/JR/D GLV C/O (09/18112) WELL: 12 -10A 11/01/92 LAST WORKOVER 10/02/12 SET/AD GOP/DRUG & TBG PUNCH (09/29/12) PERMT No: 1920890 05/31/06 DIM VVE-LHEAD CORRECTION 10/14/12 TTR/PJC CEMENT/ MLL PUSH DP BTM (10 /9/12) API No: 50- 029 - 20586 -01 08/13/06 DAV /PJC SSSV CORRECTION 11/10/12 BSE/ PJC GLV C/O (10/18/12) & FISH CORRECTION SEC 18, BON, R15E 768' FSL & 733' FEL 04/05/12 GJF /JND SSSV LOCKED OUT (4 /4/12) 04/18/12 PJC PERFCORRECTIONS II BP Exploration (Alaska) NORDIC - CALISTA RIG 1 CHOKE / REEL/CIRCULATION MANIFOLD DIAGRAM I V12 ' V14 7 -1116" 5000 psi BGP'a to = zos° V15 V11 •a .. I71It6' 5000 en, R %-06 Transducer rA k k E / 1 1 V2 VI � V 16 • -•lall -.4. kl— yy �� I 71116" 5000 pai, R %A6 1 11 ' V1 H CR ' I IC _' IK OK -� Buster ' A a PP 170 40 NIOntanta xVW moo pai, R0(34 ( . I 3.00'6000 per HC R II ..,"=, 111111MPIPIP NI • PC IN _. ,-...-- ..-- Manual Choke —• x 7 o7pis •'� - I _ �CI - , � • 71116 Cameron FOV Gate ! r Valve x6000 pei Ir.. / EOH /Diesel , �— FP Line CoFkx Hose 1/4 Turn Hakes 10WOG To Production Tree or Cross Over • • • T Pres e transducers CoFlez Hose CV11 0 0 CV12 To Coiled Tubing Bleed Off Inner Reel Valve 7, — . W T I �, N13 Cement Line In r Ground Level Tre-in N10 v J CV3 CV2 T Stand Pipe ° Manual Choke anua • - �.- .. - -..- -_ �- � -'°'- - '� - • _ - - -- - - Pressure Transducers Ng o4on 11 C V77 " M _ CV1 NIIMP s f1 Tiger Tank Mud Pump 2 !....1 ___________ — In From • O Z. = :— Baker MP 1 & MP 2 ease= ►t Choke • CV14 to Pits 1 Rig Floor Mud Pump #1 2 CVI6 Reverse CircrdaLno I iio III dm, — Cir CT while OOH I. i 4:30 To Manifold CV15 1-Jun -2010 Rom... rirr- ,satins Iree I CT ,uhil. Clelu CoFlez Hose • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. • Thanks, Steve D. file: / /F: \Daily_Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 RE * STATE OF ALASKA NOV 15 2012 AKA OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well Plug Perforations U Perforate U OtherU Performed: Alter Casing 0 Pull Tubing❑ Stimulate - Frac 0 Waiver 0 Time Extension❑ Change Approved Program ❑ Operat. Shutdown0 Stimulate - Other ❑ Re -enter Suspended Wel[J 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development IS Exploratory ❑ .: 192 -089 -0 3. Address: P.O. Box 196612 StratigraphiC Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20586 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028331 ' PBU 12 -10A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDFIOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10305 feet Plugs measured None feet true vertical 9130.28 feet Junk measured None feet Effective Depth measured 10262 feet Packer measured 9672 feet true vertical 9097.27 feet true vertical 8652.16 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 78 20" Conductor 32 - 110 32 - 110 Surface 2611 13 -3/8" 72# N -80 31 - 2642 31 - 2641.97 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 3128 7" 26# 13CR80 7177 - 10305 6758.24 - 9130.28 7240 5410 Perforation depth Measured depth 9936 - 9958 feet 10070 - 10090 feet 10100 - 10120 feet 10122 - 10125 feet 10125 - 10126 feet 10126 - 10135 feet 10140 - 10154 feet True Vertical depth 8848.86 - 8865.31 feet 8950.08 - 8965.34 feet 8972.97 - 8988.27 feet 8989.8 - 8992.09 feet 8992.09 - 8992.86 feet 8992.86 - 8999.75 feet 9003.58 - 9014.31 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 29 - 9740 29 - 8702.9 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Otis MHR Packer 9672 8652.16 Packer None None None SSSV 12. Stimulation or cement squeeze summary: 1 Intervals treated (measured): SCANNED FEB q` � l � 9645' - 9649' Treatment descriptions including volumes used and final pressure: 64.4 Bbls 15.8 ppg Unislurry Cement, 2000 psi. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 123 578 2111 • . 1221 238 Subsequent to operation: 141 9 1793 1239 216 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil _U Gas U WDSPLU GSTOR 0 WINJ 0 WAG ❑ GINJ ❑ SUSP 0 SPLUCC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Garry.Catron BP.Com Printed Name Garry Catron Title PDC PE Signature SSG Phone 564 -4424 Date 11/14/2012 r NuV 192012 0.Z7 /L. Form 10-404 Revised 10/2012 (.'=- j..We.._ Submit Original Only Casing / Tubing Attachment ADLOO28331 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20" Conductor 32 - 110 32 - 110 LINER 3128 7" 26# 13CR80 7177 - 10305 6758.24 - 9130.28 7240 5410 PRODUCTION 7315 9 -5/8" 47# L -80 30 - 7345 30 - 6886.91 6870 4760 PRODUCTION 60 9 -5/8" 47# S00-95 7345 - 7405 6886.91 - 6932.87 8150 5080 SURFACE 2611 13 -3/8" 72# N -80 31 - 2642 31 - 2641.97 4930 2670 TUBING 9711 4 -1/2" 12.6# 13Cr80 29 - 9740 29 - 8702.9 8430 7500 • • • Daily Report of Well Operations ADL0028331 SUMMARY emp= ' ssis me, `' - I o • • psi, irc -I iese pos •g -punc • ea Repair) Pressured up Tbg with 8 bbls diesel. Tbg lost 100 psi in 1st 15 mins and 38 psi in 2nd 15 mins for a total loss of 138 psi in 30 min test. E -line ran Tbg punch, we pumped 20 bbls of diesel down Tbg taking returns into IA and out the LTP leak to prove injectivity CONTINUE JOB ON NEXT 9/28/2012 DAY ** *WELL S/I ON ARRIVAL * ** (ELINE PLUG & TBG PUNCH) INITIAL T /I /O = 250/720/0 PSI RIH WITH MH -22 (5x3 ERS) / 2 1- 11/16" WB / CCL / FH / SETTING TOOL / PLUG. OAL = 25.5', OAW = 240 LBS, MAX OD = 3.66 ". SET 4 -1/2" HES COMPOSITE PLUG AT 9735', LRS MITT TO 2500 PSI PASSED /, RIH W/ MH -22 (5x3 ERS) / 2 1- 11/16" WB / SWIVEL / MPD / CCL / FIRING HEAD/ TBG PUNCH ° /B MAX OD = 1.69 ", OAL = 32', SHOT 4 SPF, 0 DEG PHASE TBG PUNCH FROM 9645' -9649' FINIAL T /I /O = 750/500/0 PSI 9/28/2012 ** *WELL S/I UPON DEPARTURE - JOB COMPLETE * ** ** *WELL S/I ON ARRIVAL * ** (ELINE PLUG SET & TBG PUNCH) INITIAL T /I /O = 250/720/0 PSI RIH W/ MH -22 (5x3 ERS) / 2 1- 11/16" WB / CCL / FIRING HEAD / SETTING TOOL / PLUG. OAL = 25.5', OAW = 240 LBS, MAX OD = 3.66 ". SET 4 -1/2" HES COMPOSITE PLUG AT 9735'. LRS MITT TO 2500 PSI PASSED. RIH W/ MH -22 (5x3 ERS) / 2 1- 11/16" WB / SWIVEL / MPD / CCL / FIRING HEAD / TBG PUNCH / BOWSPRING MAX OD = 1.69 ", OAL = 32', FISHING NECK = 1.38" SHOT TBG PUNCH FROM 9645' -9649' FINIAL T /I /O = 750/500/0 9/28/2012 ** *WELL S/I UPON DEPARTURE - JOB COMPLETE * ** * ** WSR Continued from 9- 28 -12 * ** T /I /O = 2495/2410/0 (LTP Leak Repair) Circ diesel post E- line Tbg punch pumped 20 bbls prior to midnight at a rate of 0.20 bpm (8.4 gpm) Pumped a total of 38 bbls of diesel for Tbg FP and establish a LLR of 0.20 bpm (8.4 gpm) FP flow line with 40 bbls re- claimed 60/40 from DS 12 tankTags hung, DSO notifed at time of departure. Final WHPs 1500/1840/0 9/29/2012 SV, SSV, WV, CV, IAGL = Closed MV, IA, OA = Open CTU #3 1.75" Coil Tubing- Job Scope: Repair LTP leak MIRU Perform Circ out. RIH and tag CBP at 9735'. PUH to 9725' and standby for Biozan. 10/7/2012 ** *Job continued on 10/8/12 WSR * ** 10/7/2012 CTU #3 1.75" Coil Tubing- Job Scope: Repair LTP leak= MIRU Perform Circ out. RIH to tag Plug. Daily Report of Well Operations ADL0028331 CTU #3 1.75" Coil Tubing- Job Scope: Repair 7" LTP leak Stand by for Biozan due to CTU #8 needing it for G -08 cement job prematurely setting up. Biozan on location, begin mixing 65bbls 15.8ppg Unislurry cement. Pump a 5bbl freshwater spacer followed by 64.4bbls of 15.8ppg Unislurry cement followed by 34.2bbls freshwater to sweep coil of cement. Line up down backside and pump 64.4bbls of 1 %KCI taking diesel returns from IA to an OT tank. Perform squeeze to 2000psi in 500psi increments. Est top of cement on backside is 6833' in IA. RIH jetting BIO from 7700' to 9730' make 3 passes. PUH to 9550' chase BIO out at 80% with KCL recip across GLM's. Jet across BOP's and tree RBIH to 500' freeze protect with 10/8/2012 50/50 meth. POOH. At surface trap pressure on tbg to hold cement in place. Stack down WOC. • CTU #3 1.75" Coil Tubing- Job Scope: Repair 7" LTP leak Stand by for Biozan due to CTU #8 needing it for G -08 cement job prematurely setting up. Biozan on location, begin mixing 65bbls 15.8ppg Unislurry cement. Pump a 5bbl freshwater spacer followed by 64.4bbls of 15.8ppg Unislurry cement followed by 34.2bbls freshwater to sweep coil of 7c cement. Line up down backside and pump 64.4bbls of 1 %KCI taking diesel returns from IA to an OT tank. Perform squeeze to 2000psi in 500psi increments. Est top of cement on backside is IA 6833' in IA. RIH jetting BIO from 7700' to 9730' make 3 passes. PUH to 9550' chase BIO out at 80% with KCL recip across GLM's. Jet across BOP's and tree RBIH to 500' freeze protect with 50/50 meth. POOH. At surface trap pressure on tbg to hold cement in place. Stack down and WOC. MU BKR motor and 5- bladed Opticut mill and RIH. MIT -IA to 500 psi. There is — 500psi hydrostatic diff. between TxIAw/ cement in IA. 10/8/2012 ** *Job continued on 10/9/12 * ** CTU #3 1.75" Coil Tubing- Job Scope: Repair 7" LTP leak ** *Job continued from 10/8/12 WSR * ** 10/9/2012 Perform MIT -IA to 500psi - unsuccessful. POOH. FP tubing w/ 50/50 methanol. • CTU #3 1.75" Coil Tubing- Job Scope: Repair 7" LTP leak ** *Job continued from 10/8/12 WSR * ** Perform MIT -IA to 500psi - unsuccessful. POOH. FP tubing w/ 50/50 methanol. RIH w/ 3.08" ctc, 3.13" dfcv, jars, 3.38" disco, 3.13" circ sub, 3.15" motor, 3.1" motor, 3.1" crossover, 3.72" Bo -Mill. (oal= 25.47'). Perform passing MIT -IA to 2000 psi. Phone town. Obtain approval to mill plug. Tag and mill thru plug at 9723 and chase to 10165' (corresponds with last tag depth). pooh. Freeze 10/9/2012 protect well w/ 38 bbls 50/50 meth. * *job complete ** T /I /O = Vac/Vac /55. Temp = SI. Tubing, IA FLs. (FB Request). ALP = 1980 psi, AL SI @ casing valve. Tubing FL near surface ?. IA FL near surface ?. Fluid level shots difficult to obtain due to strong Vac in tubing & IA. 10/12/2012 SV, WV = C. SSV, MV = O. IA & OA = OTG. NOVP. 09:50 Daily Report of Well Operations ADL0028331 T /I /0 =- 12/72/273 MIT -IA to 3000 psi PASSED lost 121 and 38 psi pumped 5.3 bbls neat to reach test pressure bled IA back to 439 psi rig down (well shut in on arrival and departure swab 10/13/2012 closed,wing closed,ssv open, master open,annulus valves open to gauges)FWHP =- 11/439/336 T /I /O 0/20/0 Temp =SI Assist slickline (load tbg) Pump 16 bbls crude down tbg FWHP 0/20/0 SLB 10/18/2012 on location at departure * **WELL SHUT -IN ON ARRIVAL * ** (post -pkr- squeeze) SET 4 -1/2" WHIDDON C -SUB AT 9,722' SLM (9,727' MD) PULL RK 1 -1/2" DUMMY GLV FROM STA #2 @ 5285' SLM / 5290' MD PULL RK 1 -1/2" DUMMY GLV FROM STA #1 @ 3331' SLM / 3341' MD SET RK 1 -1/2" DOME GLV (1500 tro 1/4" ports) IN STA #1 @ 3341' MD SET RK 1 -1/2" ORIFICE GLV (20/64" ports) IN STA #2 @ 5290' MD PULLED EMPTY WHIDDON CATCHER SUB FROM 9722' SLM 10/18/2012 ** *WELL LEFT S /I, DSO NOTIFIED * ** T /I /O = 190/1230/540. Temp = Hot. WHPs. (Eval high OAP). AL online @ 1230 psi. 10/22/2012 SV = C. WV, SSV, MV = 0. IA & OA = OTG. NOVP. 14:30 i I 1 TREE= GRAY GEN 4 4111 WELLHEAD = GRAY SA NOTES: """ CHROME TIMING 8 LNR """ AC,UAT �' 'I 2-1 OA KB. REV 7 KB = BF. ELEV = , - KOP = 44W Max Angle = 42°787T Dam MD = �� tu 9965' 2050' — 4IMP 1/2" CAMCO IMP SSSV NP, D = 3.813" Datum T1J0 = -- TRDR 1A LOCKED OUT (04/04/12) 13 -3/8" CSG, 72#, N-80, D = 12.347" H 2642 -A GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATQ-1 FORT DATE Minimum ID = 3.725" @ 9727' f 'R. 1 3341 3340 2 MIVIGM a4/` RK 0 10/18/12 2 5290 5222 32 MMGM DMY RK 0 10/18/12 4 -1/2" OTIS XN NIPPLE V ► � ►V. 3 6744 40 _ MMGM DMY RK _ 0 _10/18/12 A .,. I I I 6833' —1 ESTM ( ATID TOP OF CE (10/08/12) I ITOP OF 7" LNR 7177' - ■ * CI"- ►4 * � 9 -5/8" SECTION WINDOW 7345' - 7405' 1 9-5/8" CSG, 47 #, L- 80/SOO -95, D = 8.681" H 7405' 1 � /;I 1 4 1 . t! t . .4l 44,.. * � ' � . 9653' H4-1/2" PARKER SWS NIP, D = 3.813" TBG PUNCH, 4 SFF (09/29/12) H 9646' - 9649' 1 4444444 4 4 4 44 4 9672' H7" X 4-1/2" OTIS MFR D PKR, = 3.875" I • ',; ∎444 ••∎ 4 ': 4 9706' 1- 141/2" PARKER SWS N3= 3.813" I ■ e4�4�4�4�4�4�4 • 4 •4 4 9727' -- 141/2" OTIS XN NIP, D = 3.725" ■ ■4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 •4 4 •4 4 •4 •4 4 4 4 4 4 4 4 4 4 •4 44444444444 4 4 4 4 4 44 4 4 4 9-5/8" F ES BRIDGE PLUG 1-1 7605' 9740' H41/2" WLEG 1 9729' H ELMD TT LOGGED 11/16/92 1 x . 4-1/2" TBG, 12.6#, 13- CR-80, .0152 bpf, D = 3.958" H 97410' ` PB2FORATION SUMMARY ‘ — FISH -CAP - MLLE!) REF LOG: BRCS ON PUSHEI) TO BTM & ANGLE AT TOP PERE: 42° @ 9936' (10109 \12) Note: Refer to Production 06 for historical pert data ` SIZE SPF INTT32VAL Opn/Sqz DATE 3-318" 4 9936 -9958 0 10/18/93 3-3/8" 4 10070 -10090 0 11/15/92 3-3/8" 4 10070 -10090 0 04/08/01 . 3-3/8" 4 10100 -10120 0 04/08/01 3-3/8" 6 10122 -10126 0 07/15/94 3-3/8" 4 10125 -10135 0 04/08/01 3-3/8" 6 10140 -10154 0 07/15/94 /,,, I I FBTD 10262' X , 41 ∎4%4% 4i \ , 1 , 1 7" LM , 26#, 13-CR-80, .0383 bpf, D = 6.276" H 10305' , DATE REV BY COM ENTS DATE REV BY COI& EJTS PRRUDHOE BAY UNIT 11 /01/92 ORIGINAL COMPLETION 09/21/12 MSS/JMD GLV 00 (09/18/12) WELL: 12 -10A 11/01/92 LAST WORK13VB2 10/02/12 SET /JMD COMP FLUG & TBG PUNCH (09/29 /12) PEWIT No: `1920890 05/31 /06 DTM WELLHEAD CORRECTION 10/14/12 TTR/PJC C RE T/ MLL RUSH BP BTM (10 /9/12) AFIRE 50- 029 - 20586 -01 08/13/06 DAV /PJC SSSV CORRECTION 11/10/12 BSE/ PJC GLV C/O (10/18/12) & FISH CORRECTION SEC 18, BON, R15E 768' FSL & 733' FEL 04/05/12 GJF /JMD SSSV LOCKED OUT (4/4/12) , 04/18/12 PJC Fi3 FC ORRECTIONS 1 BP Exploration (Alaska) • • ALMA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Garry Catron Petroleum Engineer - D ' BP Exploration (Alaska), Inc. ` P.O. Box 196612 Anchorage, AK 99519 -6612 - - - Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12 -10A Sundry Number: 312 -206 Dear Mr. Catron: StrANNED JUL 0 3 2012 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 / 7 Daniel T. Seamount, Jr. Commissioner DATED thia day of June, 2012. Encl. STATE OF ALASKA 2 '44 • ft ECEIVED ALODA OIL AND GAS CONSERVATION COMMON ,3r` APPLICATION FOR SUNDRY APPROVALS JUN 0 6 2012 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well El • Ch. °_ _ 0 0' 0 ram ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown El Re-enter Other: CY►'� -�' �cs -tl�-1 Re -enter Susp. Well ❑ Stimulate Alter Casing 4 a- 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Ei • Exploratory ❑ 192 -0890 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20586 -01 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 12 -10A • Spacing Exception Required? Yes ❑ No 0 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028331 ' PRUDHOE BAY Field / PRUDHOE OIL Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10305 • 9130 • 10262 9097 9727' NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" Conductor 32' 110' 32' 110' Surface 2611' 13 -3/8" 72# N -80 31' 2642' 31' 2642' 4930 2670 Production 7315' 9 -5/8" 47# L -80 l 30' 7345' 30' 6887' 6870 4760 Production 60' 9 -5/8" 47# S00-95 l 7345' 7405' 6887' 6933' 8150 5080 Liner 3128' 7" 26# 13CR80 7177' 10305' l 6758' 9130' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# 13Cr80 29 9740 Packers and SSSV Tvoe: 4 -1/2" OTIS MHR PKR Packers and SSSV MD and TVD (ft): 9672' 8652' 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 111 ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/19/2012 Oil El • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Title PE Signature R ,y Phone 564 4424 Date " 6/5/2012 Prepared by Nita Summerhays 564 -4035 J C � COMMISSION USE ONLY (� / Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1 1 �--2 �.J( 2 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: a 4 APPROVED BY � �� App oved by: 1 / / COMMISSIONER THE COMMISSION Date 002.--. . 1.' `; • S JUN 1 z VLr F . ` .rm 10 -403 Revised 1/2010 ORIGINAL Submit in Duplicate L (®ill / Zv% Z/ 12 -10A 192 -089 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 12 -10A 11/15/92 PER 10,070. 10,090. 8,950.08 8,965.34 12 -10A 10/18/93 APF 9,936. 9,958. 8,848.86 8,865.31 12 -10A 7/15/94 APF 10,122. 10,126. 8,989.8 8,992.86 12 -10A 7/15/94 APF 10,140. 10,154. 9,003.58 9,014.31 12 -10A 4/8/01 APF 10,070. 10,090. 8,950.08 8,965.34 12 -10A 4/8/01 APF 10,100. 10,120. 8,972.97 8,988.27 12 -10A 4/8/01 APF 10,125. 10,135. 8,992.09 8,999.75 12 -10A 3/14/12 BPS 9,727. 9,936. 8,693.21 8,848.86 12 -10A 4/3/12 BPP 9,727. 9,936. 8,693.21 8,848.86 12 -10A 4/5/12 BPS 9,727. 9,936. 8,693.21 8,848.86 • AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 dap • 0 I! I To: C. Olsen/ T. Norene (ADW Well Service TL) Date: May 22, 2012 J. Bixby/ R. Liddelow (ADW Wireline TL) From: Josiah Igwe WDE AFE: APBNRWOS Cartron Garry PE Subject 12 -10A LTP Repair IOR: 180 bopd Sundry: Needs a Sundry prior to commencing work. Step Description Comment 1 S Pull PXN plug, SBHP, Drift with dummy 4 -1/2" Composite plug /Dummy GLV. 2 E Set composite bridge plug and punch tubing. 3 C Perform cement packer repair, mini - MIT -IA, and mill cement/ composite plug. 4 F WOC 3 days and perform a MIT -IA to 3000 psi. 5 SP Drift and Tag TD /Install LGLV Current Status Producer — SI Last Test 2/26/12: 188 BOPD, 88.7% WC, 662 GOR Max Deviation 420 @ 7877' MD Min ID 3.725" @ 9727' MD, 4 -1/2" Otis XN Nipple Last Tag 3/11/12: 10,157' SLM w /20' x 3.7" Dummy Whipstock Last Downhole Op 4/4/12: Set 4 -1/2" PXN Plug @ 9727' slm Latest H2S value 02/26/2012: 30 ppm SBHP /SBHT 9/11 /02: 3309 psi, 211F • Objective � "' The objective of this intervention is to repair a leaking Liner top packer by means of cement. A composite bridge plug will be set in the production_/" and E -Line will punch tubing above the packer. Cement will be circulated up into the annulus above LTP. The remaining cement above the composite plug will be contaminated with biozan and milled up when the cement develops 500 psi compressive strength ( -4 -5 hours, cement samples from lab will be used for time determination). A MIT -IA will be performed to determine the success of this squeeze. li Well History Well 12 -10 was drilled in May 1981. It produced for about 10 years until performance dropped off and water production increased. It was sidetracked in November 1992 and has been a stable waterflood producer ever since. Both the Sag and Zone 4 have been frac'd and well shows MI response from 12 -31 and 12 -33 as evidenced by cyclical GOR. In April 2001, fifty feet of upper Zone 4B was perforated to ensure communication with the entire LOC. No benefit was observed as a result of this wellwork. In December 2011 it was decided to sidetrack this well to the East while maintaining current fault block production. Subsequent CTD Screening work discovered a leak near the top of the liner at 7188' MD into the formation. q Page 1 of 7 cc: Well File • 12 -10A Packer Repair 1. Slickline 1. RIH and retrieve 4 -1/2" PXN plug at 9727'. 2. Drift to the end of the tubing with dummy 4 -1/2" composite bridge plug and TEL. 3. DGLVs 4. RDMO 2. E -Line Perforation: 1. MIRU E -Line. 2. MU tool string with 4 -1/2" composite plug. 3. RIH and set plug at 9735', confirm plug set as per Tool Representative' instruction and POOH o Tie into tubing tally dated 10/31/92 o MIT -T to 2500 psi to ensure no Teaks 4. MU 2" tubing punch • Ensure the BHA is centralized. • Tie - into tubing tally 10/31/92 5, RIH and gently tag composite plug. 6. PUH and punch holes at the interval 9649' - 9647', POOH. • Confirm there is hole on the tubing puncher • Establish circulation with 50 bbls of diesel through the tubing out to the IA into the formation to ensure communication between tubing and IA. 7. RDMO Cementing Specifications: 50 bbls of pumpable15.8 ppg Unislurry Cement - 6 -8 hours thickening time(3 hrs mixing time, 1.5 hrs pumping time, 1 hr circulation time, 1 hr contamination time) 10 hours to reach 500 psi compressive strength - Bottom hole circulating temperature: 180 OF - Static bottom hole temperature: —211 OF Perform a UCA test and a thickening time test on the field blend prior to rigging up. I i 3. CT Cement squeeze: 1. RU 1.75" CT. The RU should include a reverse out skid to allow returns from either the IA or the CTxT (backside). It will also need to allow the cementers to pump down the coil while taking return up the IA or backside. Page 2of7 2. Bleed any gas off the IA anSG. • 3. MU & RIH with a ball drop cementing nozzle and RIH to composite plug. Take pipe displacement returns from the backside. Tag the composite plug and pick up until full string weight is observed. Correct depth to 9735 MD' (depth of plug in relation to the completion schematic). This depth correction will now put the nozzle on depth with the completion equipment in the tubing. 4. PUH 10' and flag pipe. 5. Circulate 135 bbls of diesel followed with 250 bbls of 1% Kcl down backside and take returns through the IA. 6. Close IA. 7. Begin packer repair by pumping down the coil taking returns up IA according to the following pump schedule: a. 5 bbls of inhibited fresh water b. 50 bbls of 15.8 ppg unislurry cement. c. 1 CT volume ( -32 bbls) of freshwater to displace cement to the nozzle. d. Biozan 8. When cement reaches the nozzle, CT depth should be at the flag (10' above the composite plug). Allow cement to get 100' above the nozzle and then lay in cement 1:1. Time the nozzle depth such that the nozzle depth and cement top (6446') are equivalent as the last of the cement leaves the nozzle. Because of the volume of cement being pumped, the timings must be very accurate so as not to contaminate the cement. 9. Once last of cement leaves nozzle PUH to safety -300' above WCTOC. Ensure coil speed is in excess of 100 fpm to avoid stringing cement up hole. With 50 bbls of cement, the expected top of cement in the 4-1/2" tubing should be 6446' MD, putting safety at -6150' MD. 10. Freeze protect the coil down to 2500' taking returns from the backside. 11. With CT at safety, open IA and circulate exactly 49 bbls of cement into the IA by pumping diesel down the backside and taking returns from the IA. Once 49 bbls have been circulated into the IA, shut in IA. The IA will remain shut in for the remainder of the job. While it is not critical that a constant IA pressure is maintained, it is important that the well is not surged. Do not let IA pressure bleed down or cement will u -tube. 12. Swap to 3.0 ppb biozan and drop ball. With biozan at the nozzle jet down to top of composite plug (tag plug). PUH while continuing to jet biozan and ensure 3.0 ppb biozan is spotted across the tubing. This will serve 2 purposes: the 3.0 ppb biozan should help keep the cement in the IA by acting as a viscous barrier. It will also help keep any residual cement in the tubing contaminated. 13. With slick 1% KCL at the nozzle proceed with a standard cement clean out, jetting to surface at 80% withdrawal speed, washing all jewellery on the way out of hole. Please perform extra jetting at GLMs as POOH. 14. Wait 10 hours on cement, then perform 500 psi compressive strength test / mini MIT -IA to 500 psi. If MIT -IA passes, mill composite and push to the bottom. If fails, RDMO CT. 4. Fullbore - Post Packer Squeeze (Pending "mini" MIT -IA passing) 1. After 3 days WOC, MIT -IA to 3000 psi. If the MIT -IA fails establish a leak rate. 5. Slick Line: 1. MIRU Slick Line 2. RIH and Re- install LGLV on station #1 and Screened Orifice on #2. 3. RDMO Page 3 of 7 • • Sc hlumberger Laboratory Cement Test Paper Pilot Report Sig na tu res F luid No : PAK Iinr09072 Client BP Exploration Location / Rig Date Well N ame Field M . Schinnell Job Type Depth 14164.0 ft TVD 10134.0 ft BHST 209 degF Bt t C T 173 degF BHP 4900 psi Starting Temp, 80 degF Time to Temp. 00:38 hr:mn Heating Rate 2 degF /min Starting Pressu 807 psi Time to Pressure 00:38 hr:mn Schedule 9.19.3 Composition Slurry Density 15.80 Iblgal Yield 1.17 ft31sk Mix Fluid 5.105 gallsk Solid Vol. Fraction 41.6 % P o rosity 58 4 % Slurry type Conventional Code Concentration Sack Refe Cornpwle.nt Blend Density Lot Number G 94 lb of CEMENT Blend 199.77 iblft3 Fresh water 5.105 gal /sk Base Fluid D046 0.200 %BWOC Antifoam TU8L0020A0 D065 0.350 %BWOC Dispersant 20080802 D167 0.450 %BWOC Fluid loss 11581713071 D153 0. %BWOC Antisettling 102608 -2 D198 0. 420 %BWOC Retarder 02- 22 -08 -08 Rhea' • • Avera • e readin t s Irpmi Ideg) deg} 300 120.0 144.0 200 86.0 109.5 100 49. 67.0 60 32.5 46.5 30 18.5 27.5 6 5.8 7.7 3 4.2 4.8 10 sec Gel 5.8 4.0 10 min Gel 323.6 14.3 Temperature 1 80 degF 1 173 degF P 112.341 cP Pv:128.557 cP Tr : 9.74 Ibf/ 100ft2 Tv: 20.14 Ibf /100ft2 Thickenin Time 30 Bc 08:08 hr :mn 70 Be 09 :05 hr:mn 100 Bc 09:14 hr:mn Free Fluid 0.0 mL/250mL in 2 hrs At 80 degF and 45 deg incl. Sedimentation None Fluid Loss API Fluid Loss 68 ml 34 mL in 30 min at 173 degF and 1000 psi Page L Page 4 of 7 • • f ' r y 1 I PDS Leak Detect Log 03 -21 -2012 r 1 t , , 7100 k t I L ./ t { - . G :M M3 leak Signature `� L iKe. , e 1 JP-- ir) -, _.___.�_,^ �' .. r 1 1 r t t ` 1 1 F i , , f t i tI : t { f 1 j ■ �, i I t,,, 1400 J i i ( f I , - il. 1 1-' \ i ; t 1 4 . + I Al t\ . ..e'? , 774Y1 I I Page 5 of 7 Dri imp r : ::z>:::::::::i;:;:::i:::5:::: �;: i:>:• i':; :;.>:.:::;::;i::'::;<;:i:;: :::::R2:: � ::::i;: iS ::iR:::;:;::::::;::: ;::':Y•;:>: >::;>: 2:: t:: ;:::::;: ?:.: } .>::>:i:;t;;a' ITEM ID OD LENGTH TOP BOTTOM 4.5 "W /LEG 3.958 5.340 0.87 9739.19 9740.06 10'X4.5 "12.6 #13CR -80 PUP JT. 3.958 5.030 10.13 9729.06 9739.19 4.5" XN NO -GO NIPPLE 3.725 4.980 1.63 9727.43 9729.06 4.5" 12.6 #13CR -80 PUP JT. _ 3.958 5.030 10.08 9717.35 9727.43 10' X4.5" 13CR -80 TDS. PUPJT. _ 3.958 5.030 10.05 9707.30 9717.35 4.5 SWS LDG. NIPPLE 9 -CR 3.813 4.960 1.64 9705.66 9707.30 4.5" 12.6 #13CR -80 TDS PUP JT, 3.958 5.230 19.35 9686.31 9705.66 10'X4.5 "12.6 #13CR TDS PUP JT. 3.958 5.230 9.08 9677.23 9686.31 7 "X4.5" 26 -32# MHR PKR. 3.875 5.875 5.67 9671.56 9677.23 OTIS PKR.RUNNING TOOL/ANCHOR 5.000 1.49 9670.07 9671.56 5 "X4.5" 12.6 #13CR -80 TDS PUP JT 3.958 5.230 4.97 9665.10 9670.07 4.5 "12.6 #13 -CR80 FOX PUP JT,XO 3.958 5.230 9.98 - 9655.12 9665.10 4.5" SWS LANDING NIPPLE 9CR 3.813 4.960 1.64 _ 9653.48 9655.12 10X4.5 "12.6 #13CR -80 TDS PUP JT. 3.958 5.230 9.62 9643.86 9653.48 63 jts. 4.5" 12.6 #13CR -80 3.958 5.230 2466.14 7177.72 9643.86 10'X4.5'12.6 13CR-80TDS PUP 3.980 5.230 9.56 7168.16 7177.72 CAMCO 4.5"TDS MMGM GLM W /RKED 3.883 6.437 8.69 7159.47 7168.16 10'X4.5 "12.6 #13CR80 TDS PUP 3.980 5.230 10.03 7149.44 7159.47 47JTS 12.6 #13CR80 TDS 3.980 5.230 1840.86 5308.58 7149.44 10'X4.5 "12.6 #13CR -80 TDS PUP JT 3.980 5.230 ` 9.98 5298.60 5308.58 CAMCO MMGM GLM W DUMMY 3.883 6.437 8.66 5289.94 5298.60 10'X4.5 "12.6 #13CR -80 TDS PUP 3.980 5.230 10.06 5279.88 5289.94 49JTS 4.5 "12.6 #13CR -80 TDS 3.980 5.230 1920.76 3359.12 5279.88 10'X4.5'12.6 113CR -80 TDS PUP 3.980 5.230 9.97 3349.15 3359.12 CAMCO MMGM GLM W /RP 3.883 6.473 8.66 3340.49 3349.15 10'X4.5 "126 #13CR -80 TDS PUP 3.980 5.230 10.06 3330.43 3340.49 32JTS 4.5" 12.6 #13CR -80 TDS 3.980 5.230 1257.91 2072.52 3330.43 12.6 #13CR -80 PUPJT 3.980 5.230 9.51 2063.01 2072.52 12.6 #13CR -80 X0 PUP 3.980 5.230 1.81 2061.20 2063.01 4.5 "FLOW CPL. FOX 13CR -80 3.958 5.030 5.66 2055.54 2061.20 CAMCO TRSV 3.813 7.170 5.68 2049.86 2055.54 4.5 "FLOW CPL.FOX 13CR -80 3.958 5.030 5.65 2044.21 2049,86 12.6#13CR -80 XO PUP 3.980 5.230 2.01 2042.20 2044.21 12.6 #13CR -80 PUPJT 3.980 5.230 9.39 2032.81 2042.20 52 JTS 12.6 #13CR -80 TDS 3.980 5.230 2007.66 25.15 2032.81 VETCO GRAY TBG HANGER TDS 3.980 5.230 3.35 21.80 25.15 LANDING -JT 12.6 #13CR -80 TDS 3.980 5.230 21.80 0.00 21.80 0.00 0.00 0.00 T - Page 7 of 7 • • TREE = GRAY GEN 4 WELLHEAD = GRAY SAFETY NOTES: "' CHROME TUBING b LNR*** ACTUATOR- OTIS 12 -10A ' KB. ELEV = 71' BF. ELEV = 'KOP= 4400' Max Angle = 42° @ 7877' 2050' — 4-1/2' CAMC.O TRDP SSSV NIP, ID = 3.813" Datum ND= 9965' Datum TVG = 8800' SS • TROP-1A LOCKED OUT (04104/12) 1 113 -3/8" CSG, 72 #, N-80, ID = 12.34T H 2642' GAS LIFT NIAt+![�tELS ST NO TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.725" @ 9727' 1 3341 3340 2 CA MMGM DOLE RK 16 16 06/05/09 4-112" OTIS XN NIPPLE 2 5290 5222 32 CA MGM DONE RK 16 06/05/09 3 7159 6744 40 CA WVGM SO RK 22 _06/05!09 ITOPOF 7" LNR H 7177' 1°4:k; t 7 9 -5/8" SECTION WINDOW 7345' - 7405' 1 9-5/8" CSG, 47 #, L -80 /SO0-95, ID = 8.681" (—{ 7405' ,/ 14 t{ :■ 1'1 q L h 1' 1 ' 9' \1 1 `n' ) X ik +11 ` 9653' I- �4- 1 /2' PARKER SWS NIP, ID= 3.813" I 1 e1111 ∎1 9672' H' X 41 rr OTIS NHR FKR, ID = 3.875" I ■•••■\ ∎1 ;, 1 1 1 11 1 1 1 1 1 1 1 9706' Ha -12" PARKERSWS NIP, ID= 3.813" I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11111111 9727' 4-12" OTIS XN MP, ID = 3.7259 11 N � 111111 + 1111111111 - al ■ Kali 4 -112" PXN PLUG (/)4/04(12) 11 • 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 •/ 1 1 / :.•.4,11•■■•■■•1 9740' _I- 141/2" WLEGI (9 -5/8" HES BRIDGE Ft.UG H 7605' I 9729' Halm U LOGGED 11/16/92_1 1 4-12" TBG, 12,6#, 13- 0R-80, .0152 bpf, ID = 3.958" 9740' ` PERFORATION SUMMARY ` REF LOG. BHCS ON 10/28/92 ANGLE AT TOP PERF: 42° @ 9936' Note: Refer to FYoduction DB for historical perf data ` SIZE SPF INTERVAL OpnlSgz DATE 3.3/8" 4 9936 -9958 0 10/18/93 3-3/8" 4 10070 -10090 0 11/15/92 3-3/8" 4 1C070-10090 0 04/08/01 33/8" 4 10100 -10120 0 04/08/01 33/8" 6 10122 -10126 0 07/15/94 3-318" 4 10125 -10135 0 04/08/01 33/8" 6 10140 -10154 0 07/15/94 1 4 1 4 44 0k PBTD' 10262' 1 1 1 1 Jr ' LNR, 26 #,13- CR-80, .0383 bpf, ID = 6276" I—I 10305' ► DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11101192 ORIGINAL COMPLETION 02/09/11 M13/JA/0 REMVD SSSV SAFETY NOTE WELL: 12 -WA 11/01/92 LAST WORKOVER 03/20/12 DAS /JND SET CAT STANDING VALVE (03/13/12' PERMTNo: 192 -0890 05/31/06 DTM WELLHEAD CORRECTION 04/05/12 GJF /JM) PULL CAT VALVE/SET PXN PLUG (04/C API No 50 -029- 20586 -01 08/13/06 DAV /PJC SSSV CORRECTION 04/05/12 GJF /JMD TRDP -1A LOCKED OUT (0404/12) SEC 18, DON, R15E 5140.02 FEL 1996.39 FNL 06/14/09 DAV/TLH GLV C/O (06/05/09) 04/18/12 PJC PERFORATION CORRECTIONS 12/17/10 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) Page 6 of 7 \‘ 2. o'� Z-1 4 SCHLUMBERGER STATE OF ALASKA AOGCC ALASKA DATA & CONSULTATION SERVICES 333 W. 7th AVE 2525 GAMBELL STREET, SUITE 400 SUITE 100 ANCHORAGE, AK 99503 -2838 ANCHORAGE, AK 99501 ATTN: STEPHANIE PACILLO ATTN: MAKANA BENDER WELL SERVICE OH RESV CNL LOG DESCRIPTION DATE B/W COLOR CD NAME ORDER # DIST DIST DIST Prints Prints 11 -38A BD88 -00196 X MEMORY TEMP SURVEY 7- Feb -12 1 1 H -22A BUTT -00059 X MEMORY LEAK DETECT LOG 19- Feb -12 1 1 • 13 -03A BD88 -00195 X MEMORY PPROF 5- Feb -12 1 1 B -29A BUTT -00061 X MEMORY PPROF 25- Feb -12 1 1 J -26 BAUJ -00111 X MEMORY LEAK DETECT LOG 6- Feb -12 1 1 L4 -18 BBRC -00166 X MEMORY LEAK DETECT LOG 5- Mar -12 1 1 V -105 BAUJ -00109 X MEMORY IPROF 30- Jan -12 1 1 12 -10A BD88 -00202 X MEMORY PPROF 6- Mar -12 1 1 P -15L1 BBSK -00105 X LEAK DETECT LOG 18- Feb -12 1 1 S -05A BD88 -00201 X MEMORY IPROF 17- Feb -12 1 1 Y -19 BINC -00091 X PRIMARY DEPTH CONTROL 9- Jan -12 1 1 P -01A BD88 -00193 X MEMORY DEPTH DETERMINATION 15- Jan -12 1 1 MPJ -11 BAUJ -00100 X MEMORY IPROF 17- Aug -11 1 1 MPL -33 COT4 -00005 X MEMORY (PROF 22- Feb -12 1 1 • TRANS #: 5915 DATE: 30- Mar -12 X VAC X Please Return a Signed op; to: Please Return a Signed Copy to: BP PDC LR2 -1 900 E Benson Blvd Anc AK 99508 DCS 2525 Gambell St Ste 400 Anch AK 99503 J: ; 7.1 JUL 12 2012 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervis°r'"'~' ~;..{3 \ DATE: May 7, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit Drill Site 12 Monday, May 7,,2001: I traveled to BPXs Drill Site 12 and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 21 wells and 42 components with 1 failure. The surface safety valve on well 12-12 had a slow leak when pressure tested. This valve was serviced and retested by the operator on this date. Bill Preston (lead DS operator) performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at BPXs Drill Site 12. PBU DS 12, 21 wells, 42 components, 1 failure 2.3% failure rate 29 wellhouse inspections Attachment: SVS PBU DS 12 5-7-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU DS 12 5-7-01 CS Alaska Oil and Gas Conservation Commiss.on Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Prudhoe / PBU / DS 12 Separator psi: LPS 160 HPS 5/7/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip, Code Code Code Passed GAS or CYCLE · "i'2_0~ 1790230 '' 12-02 1~90320 12-03 1790410 160 150 150 P P OIL 12-04A 1811870' '160 150 150 P P OIL 12-05 1790550 12-06A 1920540 160 150 150 P P OIL 12-07A 1811750 160 150 140 P P OIL 12'08B 18116'70 160 150 ..... 1'~0 P P OIL 12-09 1800930 .... 160 " 150 125 ' P P OIL J , ~ti2-tOA ':i¢ 1920890 160 150 150 P P OIL 12-11 1810730 12-12 1810830 160 150 90, ,,P 4 OIL 12-13B 1960170 '160 ' 150 '150 p ' p OIL , 12-14A 1981460 160 150 150 P P OIL 12-15 ' 1830320 160 ' 150 150 P '' P " OIL 12-16A 1931480i 160 ' 150 150 P P OIL ,, 12-17 1830040: 160 150 150 P P OIL 12-18 '" 18220601 160 1'50"' 150 P P OIL 12-19 1821980 12-20 1821910i 12-21 1840480 12-22 1840600 160: 150 '" 125 P P OIL 12-23 1840580 , 12-25 1831660 12-26 1840140 160 150 '125 P P 'OIL, 12-27A 1990390 12-28A 1990330 '160 150 '170 "P P " OIL 12-29 1840320 '"" ' , , , 12-30 1881420 12-31 1890010 12-32 1890110 160 ' 150 i50i P P 0IL , , , , 12-33 1890100 12-34 'i941370 i60 150 '150 ' P' P ..... OIL 12-3S 1951300 160 lS0 100 12-36 1951580 1'60 150 150 ''P P OIL RJF 1/16/01 Page 1 of 2 SVS PBU DS12 5-7-~C_S Number Trip Wells: 21 Test Code Components: 42 Failures: Test Code Code Passed [ GAS or CYCLE Failure Rate: 2.38% l--190 ray Remarks: Surface Safety Valve on well 12-12 had slow leak when pressure tested. RJF 1/16/01 Page 2 of 2 SVS PBU DS12 5-7-01 CS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pedorate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_X RKB 71 feet , =, 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4508' FNL, 733' FEL, Sec. 18, T10N, R15E, UM (asp's 696868, 5931081) 12-10A At top of productive interval 9. Permit number / approval number 1860' FNL, 206' FWL, Sec. 20, T1 ON, R15E, UM (asp's 697885, 5928477) 192-089 At effective depth 10. APl number 50-029-20586-01 At total depth 11. Field / Pool 1996' FNL, 5140' FEL, Sec. 20, T10N, R15E, UM (asp's 697821, 5928338) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10305 feet Plugs (measured) Tagged PBTD @ 10184' MD on 4/08/2001. true vertical 9130 feet Effective depth: measured 10184 feet Junk (measured) true vertical 9037.5 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 232 Sx AS ~ 110' 110' Surface 2571' 1 3-3/8" 2700 Sx Fondu & 400 Sx PF II 2642' 2642' Production 7334' 9-5/8" 5o0 Sx C~ass G 7405' 6933' Liner 3128' 7" 14o cuft C~ass G 10305' 9130' Perforation depth: measured 9936'-9958'; 10070'-10090'; 10100'- 10120'; 10122'- 10135'; 10140'- 10154'. true vertical 8847' - 8864'; 8951' - 8966'; 8973' - 8988'; 8990' - 9000'; 9004' - 9014'. RECEIVED Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR-80 Tbg @ 9740' MD. / PR 2 ? 2001 Packers & SSSV (type & measured depth) 7" X 4-1/2" OTIS MHR PACKER @ 9672' MD. 4-1/2" CAMCO TRSV SSSV @ 2050' MD. ~,l~tl~n ~ ~ I"".~c P.r~n~ C'~rrm~ir~n 13. Stimulation or cement squeeze summary Anchorage Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 321 952 1176 234 S ubseq uen t to operation 300 2126 1164 - 214 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations .__X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,,~, ~'X,%~ Title: DS l2SurveillanceEngineer Date April24,200! Andy Parker , Prepared by Paul Rauf .564-5799 '~ -- Form 10-404 Rev 06/15/88 · 0F I®I !AL SUBMIT IN DUPLICATE 12-10A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 4/03/2001' 4/08/2001: RIH & tagged PBTD @ 10193' MD. MIRU Wireline Unit. PT'd equip to 3000 psi. RIH w/perf guns & tagged PBTD @ 10184'. Shot 60' of perforations located f/: Reperforated 10070' - 10090' MD (Zone 4) Reference Log: BHCS 10/28/1992. 10125' - 10126' MD (Zone 4) Add perforated 10100' - 10120' MD (Zone 4) 10126' - 10135' MD (Zone 4) Used 3-3/8" carriers & all shots @ 4 SPF & random orientation. POOH w/guns - ASF. RD Wireline unit. Placed well BOL & obtained a welltest. Page 1 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 P M C:LORILMFILM.DOC L A T E E TE R IA I, HIS MAR E W UNDER K E R GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'Ii'H: Sherrie NO. 9586 Company: 7/20/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk ,~'-I I , l p.S'='.'15,40~/"~.~1/- 95233 DUALBU'RsTTDTP ..... 9'5'062.4.. .... 1 D.S~ 15-36~ ~.-7'Z.---95242 DUAL BURST TDTP .... 950602 . 1 D.S. 5-6A ,,~ ~ d"..-! / OUALBuRSTT~)TP ' 9506:~0'' 1 I" .... "'~' D.s. 5-6A -/_~ ~7 PERF RECORD 950701 1 I .. ~.S....14'28 ~f'""7...-i ._..- iNFLATABLE BRIDGE PLUG ...... " ..950630 I ..........1 .. D.S. 15-12~/~" ~,~_ ~/~ ~O LEAK DETECTION 950701 1 1 D.S. 15-;~ -'"~'. -~ PROD PRORLE ....... 9506:~' I I ............ I~s. 15,32 ~ ..... ~ 7 DUAL BURST TDT-P 950630,. I I ...... D.S. ~ I ~' -%'3 ~/(./-~- ;'~.(~/' DUAL BURST TDT-P .,9. 50623 I I , ....... ......... ,, , ....... SIGNED: Please Big ~nd return one copy of this transmittal to Sherrie at the above address. Thank you. PERMIT 92-089 92-089 92-089 92-089 DATA BHC/AC/GR DLL/MLL/GR GR/CCL PERF 92-089 PERF 92-089 PERF 92-089 PERF 92-089 PROD 92-089 SSTVD 92-089 407 92-089 DAILY WELL OP 92-089 SURVEY 92-089 SURVEY 92-089 SURVEY ~ ~ ~OGCC Individual Well Geological Materials Inventory T DATA_PLUS 92-089 SURVEY 92-089 5447 L 9930-10242 L 7332-10266 L 7100-10248 L 9650-10050 L 9650-10050 L 9650-10190 L 9700-10200 L 1300-10200 L 7332-10266 R COMP DATE: 11/15/92 R 10/14-11/02/92 R 7350-10251 SPERRY SUN R 7350-10251 SPERRY SUN R 7350-10251 SPERRY SUN R 7350-9859 T 7332-10266 OH/FINALS Page: 1 Date: 11/02/94 RUN DATE_RECVD 1 11/19/92 1 11/19/92 1 12/30/92 1 12/15/93 1 12/15/93 1 08/12/94 1 03/26/93 1 09/06/94 1 11/19/92 01/19/93 03/09/93 03/09/93 03/09/93 03/09/93 01/19/93 1 11/19/92 Are dry ditch samples required? yes ~ And received? \ Was the well cored? yes/ ~/Analysis & description received? Well is in compliance~ ~ COMMENTS yes/ yes ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: i Number of Records: September 20, 1994 P.O. Box 10036C ,nchorage, AK Transmittal #: 94111 99510,~ ~, ARCO Static Pressure Survey's Karla Zuspan/ATO- 1529 (907) 263-4310 Distribution Well I Log Date Numberi (M-D-Y) 04-19 I05-23-94 04-45i 07-05-94 11-29i 07-08-94 11-36 ~06-09-94 12-07A I06-06-94 12-10A I06-07-94 i 12-12 06-08-94 12-16A ~07-07-94 12-26 i06-08-94 13-31 i06-09-94 13-35 [06-09-94 18-01 l06-04-94 18-08 i06-10-94 Tool Type t Pressure t Pressure Survey i Pressure Surve, i Pressure !Pressure t Pressure t Pressure Surve~ I Pressure Surve~ Pressure I Pressure t Pressure Pressure Survey ~ Pressure Survey I SCH 1 SCH 1 SCH 1 SCH 1 SCH 1 SCH 1 SCH 1 SCH 1 SCH 1 SCH 1 SCH 1 SCH i ! SCH 13 Karla Zuspan Distribution: Central Files BPX State of Alaska Mobil Phillips Exxon D&M Please le receipt returr~r~ By Date: ARCO Alaska, Inc. Is a Subsidiary of AllantlcRIctg'leidCofrq3any ~__ STATE OF ALASKA ALASKA! ! AND GAS CONSERVATION CC .41SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 768' NSL, 733' EWL, Sec. 18, T10N, R15E, UM At top of productive interval 1860' SNL, 1684' EWL, sec. 19, T10N, R15E, UM At effective depth At total depth 2000' SNL, 1908' EWL, Sec. 19, T10N, R15E, UM 5. Type of Well Development X ,,, , Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 71 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-10A 9. Permit number/approval number 92-89 10. APl number 50 - 029-20586-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10305 feet 9131 feet Plugs(measured) Fill @ 10215' MD (7/15/94) Effective depth: measured 10215 feet true vertical 9062 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 232 sx AS II 110' 110' Sudace 2571' 13-3/8" 2700 sx Fondu & 400 sx PF II 2642' 2642' Production 7334' 9-5/8" 500 sx CIG 7405' 6933' Liner 3128' 7" 140 cuft Cl G 10305' 9131' Perforation depth: measured 9936-9958'; 10070-10090'; 10122-10126'; 10140-10154' true vertical 8847-8864'; 8951-8966'; 8990-8994'; 9005-9015' RECEIVED Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13 CR-80, Tbg @ 9740' MD Aiaska Oii& Gas Cons. Corr~mission Packers and SSSV (type and measured depth) 7", Otis MHR Packer @ 9672' MD; Camco TRSV @ 2050' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 'i~,. ' R.epreser~tative D~'i y ,~Verage ~.roduction or Injection Daia" Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl 548 894 1522 660 959 2595 Casing Pressure .. Tubing Pressure 234 241 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations . 16. Status of well classification as: Oil ..x, Gas Suspended. .. Service. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '/l(~,,,d,¢,.,,~_ ~ ~ Title Sr. CA Engineer Form 10-404 Rer~ 06/15/88 1195/13 cc: KZ, JWP Date ~,( ~5c'i(~q- SUBMIT IN DUPLICATE 12-10A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 7/1 2/94: RIH w/CT & jetted a fill cleanout w/biozan from 10000' to 10252' MD. 7/1 5~94: MIRU & PT equipment. RIH & tagged PBTD at 10215' MD, then RIH w/perforating gun & shot 18' of add perforations as follows: Added perforations: 10122 - 10126' MD (Z4) Ref. Log: BHCS 10/28/92. 10140 - 10154' MD (Z4) Used a 3-3/8" carrier, & shot 6 spf, at 180 degree phasing, at underbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production w/lift gas & obtained a valid welltest. ~ue~f soo w. lrgon'x:ftionc:! Ak'rx:,rt Anchorage, AK 99518-1199 ATTN: Shen~ NO. 8911 Company: Alaska Oil & Gas Cons Comm ~ Attn: Larry Grant t 3001 Porcupine Drive Anchorage, AK 99501 9/6/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar -~ · '".'~ D.S. 18-11 .. " BRIDGE PLU'~ RECORD (8~'14-94) ......... 1 I 'i .... ~ l-- Ii D.S. 16.03 '" iNJEO SURVEY (8-13-94) ........ '" 1 ..... 1 .... ~'c,~ t..~ ~_D.S. 16-01 ... INJEC SURVEY (8t 13-94) ......... 1 ...... 1 ~'V~ 3 1 D.S. 12-28 PERF RECORD (8-10-94) 1 1 ,~,~.- ~ ~'.S.' '1~-10A ..... PROD PROFILE (8-13-94) ... 1 ' 1 ,~2-~'-~/.. D.S. 12-06A ....... PROD.LOG (8-12-94) ... 1 ...... 1 ~"-V,r .D.~S......1.2-3 .......... PROD PROFILE (8-13-.94) '' 1 . ..... 1 -g,t,'~ D.S. 1.2-1 "' PERF RECORD(8-10.94) .. 1 ... 1 ~_~ '/'! ~ ..... D.$. 6-19 PROD pROFILE (8,12~94) . 1 1 2?-?~ iD.S. 0i-14 POGLMSETTING REOCRD(8-11-94) . 1 1 -~'~-?"~ D.S. 01-14 TUBING PUNCHER RECORD (8-11.94).' 1 1 ~--~'~o _ ?.S. 01-03 POGLM SETTING RECORD (8-..14-94) .... 1 1 -- VF-n JG 0 199 Please sign ~d return one copy of thi~ transmittal to Sherrie at the above address. Thank you. r~o w. International AH>od R°ad Anohorage, AK 99~18-1199 ' ATTN: $hertie NO. 8852 Company: Alaska Oil & Gas Cons Oomm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 8/10/94 Field: Prudhoe Bcty Well Log Description BL RR Sepia RF Sepia Mylar ~' - ~"f D.S. 4.26'" . .... LEAK DETECTION (7-15-.94) .... 1 1 .... '~ '~ D.$. 4-2 BAKER IBP (7-17-94) '1 1 1 rf z' ?~-- D.~. 12. loA PERF RECORD (7-.15-94) .... 1 ..... 1 .... ~'~ --~, ? _ D.S. 13.27 ... PROD PROFILE (7.- 13-94) ..... 1.. ' ........ i ........ -7'7~ (.- ~_ D-$. 7-01 . . PR .0D PROFILE (7-13-94) ...... 1 ...... 1 -'~/.,. ') t/ ~D.S. 17-8 ...... INJECTION PROFILE (7.-19-94) ..... 1 ~_o.~f'x..'/_ D.S. 16-16 ........ INJECTION PROF!LE (7-14-94) 1 . 1 -_~ 5'--.-t/~ D.S. 5-5 TUBING CUTTER RECORD (7-17-94) ". 1" 1.... ~,~ ;, / ~'""~D.S. 17; 19 . .' PROD PROFILE (7-16-94) .. '" .. 1 J. 1 -'2 ~'~ 3.. I _D.S. 6-7 .. DUAL BURST TDT-P (7-13-94) 1 1 ......... SIGNED: ~ DATE: Please ~ign and return one copy~f this transmiftal to Shertie at the above addre~. Thank you. ARCO Alaska, Inc. P. O2~ox 10O360 Anchorage, Alaska 99510 DATE: 12-1-93 REFERENCE: ARCO CASED HOLE FINALS '1-33 10-16-93 '~5_~2,~.L_2-10 10-22-93 ~2-17 10-16-93 ~22 10-22-93 ~?_~_~ 2-25 10-15-93 ~ 1~1~3 ~~2~ 1~1~93 ~13 1~1~93 ~~~19 1~1~93 ~~ 1~21~3 7~~ 1~93 7~11 1~~3 7~13 1~2~93 ~~19~ 1~7-93 ~ 1~17~3 2~ ~~~1~ 1~1~3 1~1~3 ~12-1~ 1~1~93 ~ 1~1~3 ~ 1~1~3 Please sign and return RECEIVED BY Have A Nice Day! InJ Profile ba ~ t~emel m~e~- USIT (~-ro$t~ ~) Color /PeffR~o~ ~O- Io~0 ~PeffR~ ~o ~'ooSo Collar (~] C~ ~cker} a~ ~ ~z5 Completion ~i~ -~oo receipt of data. Sonya Wallace ATO-1529 APPROVED Trans# 93144 # CENTRAL FILES # CHEVIK)N #BI~X # STATE OF ~,ASKA 1, 5" ~35°-'°~qq~ Sch 1, ~' ~h 1, ~,%2q-~o~$ ~h 1, ~' ~h 1, ~'~~Tz~ ~h 1, ~'~' 0- II ~0 ~h 1, 1,1"~'0- ~0 ~h 1, ~' Atlas 1,~' I~~ Sch 1, ~' ~h 1, ~' Sch 1, ~,~00 ~ ~h 1, ~' ~h 1, ~' ~h 1, 1"~' 0-~o6~ ~h 1, ~' ~h 1, ~' ~h 1, ~' ~500 ~1 oooo ~h 1, ~' ~h 1, W' ~h 1, W' ~h 1, W' ~~ 6~ Atlas 1, W' Atlas 1, W' ~h 1, ~' ~h L r' zo%t75 ~h # PI-r~ z.]PS # ANO8 GEOLOGY #EXXON # MOBIL ._ ..... * The correct APl# for 9-7 is 50-029-20223-00. ! STATE OF ALASKA /") [ ALASK,~" ~. AND GAS CONSERVATION CC ,IISSION ~ il ' REPORT faF SUNDRY WELL OPEHATIONS 1. Operations performed: OperatiOn shutdown , Stimulate X Plugging Perforate X (~'":~//'., I Pull tubing Alter casing __ Repair well Other ,, "~,;!:, 5. Type of Well 6. Datum of elevation(DF or KB) '~)'" '~'¥~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 768' NSL, 733' EWL, Sec. 18, T10N, R15E, UM At top of productive interval 1860' SNL, 1684' EWL, Sec. 19, T10N, R15E, UM At effective depth At total depth 2000' SNL, 1908' EWL, Sec. 19, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Development X 71' RKB feet 10305 feet 9131 feet Effective depth: measured 10065 feet true vertical 8947 feet Casing Length Size Conductor 110' 20" Sudace 2571' 13-3/8" Production 7334' 9-5/8" Liner 3128' 7" Exploratory Stratigraphic Service 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-10A 9. Permit number/approval number 92-89 10. APl number 50 - 029-20586-01 11. Field/Pool Prudhoe Bay Oil Pool Plugs(measured) Fill @ 10065' MD (11/2/93) Perforation depth: Measured depth 110' 2642' 7405' 10305' True vertical depth 110' 2642' 6933' 9131' Junk(measured) Cemented 232 sx AS II 2700 sx Fondu & 400 s× PF II 500 sx CIG 140 cu ft C I G measured 9936-9958', 10070-10090' true vertical 8847-8864', 8951-8966' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13 Cr-80, Tbg @ 9740' MD REceIVeD 1093 1572 1912 Tubing Pressure 248 284 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the fore9oin9 i~ true and correct to the best of my knowledge. Signed ~-~'" ~ ~' Title Engineering Supervisor Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 1073/6 KRF cc: SW, JWP 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 710 722 1846 -- 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure Packers and SSSV (type and measured depth) 7", Otis MHR Packer @ 9672' MD; Camco TRSV @ 2050' MD Anchorage DEC - 7 1995 Alaska Oil & Gas Cons. Commission 12-10A DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT OF SAG RIVER 10/18/93: Added perforations: 9936 - 9958' MD (Sag) 10/22/93: Ref. Log: BHCS 10/28/92. MIRU & PT equipment to 4000 psi. Loaded wellbore backside w/Water & Crude while RIH w/CT to tag PBTD at 10107' MD. Pumped 13.5 bbls gelled sand slurry, containing 2500 lbs 20/40 mesh sand, to place a sand plug over the lower set of open perforations located at: 10070 - 10090' MD (Z4) Ref. Log: BHCS 10/28/92. Made a final top of sand plug tag at 10006' MD. POOH w/CT. Rigged down. I 0/23/93: RIH & tagged top of sand plug at 10011' MD. 10/26/93: MIRU & PT equipment to 9600 psi. Pumped a Datafrac & Hydraulic Fracture Treatment using 16/20 mesh proppant, through the perforation interval located above the sand plug (listed above). Pumped 250 bbls 20# Datafrac Pre Pad @ 35 bpm, followed by Shutdown. ISIP @ 1700. Resumed Datafrac pumping 100 bbls 40# Crosslinked Pad @ 35 bpm, followed by 50 bbls 40# Crosslinked Pad @ 5 bpm, followed by 55 bbls 40# Crosslinked Pad @ 35 bpm, followed by 150 bbls 20# Gelled Flush @ 35 bpm, followed by Shutdown. ISIP @ 1872. Resumed pumping Fracture Treatment of 430 bbls 40# Crosslinked Pad @ 35 bpm, followed by 621 bbls Crosslinked Slurry w/proppant stages @ 1 - 10 ppg, followed by 65 bbls 20# Gelled Flush, followed by Shutdown. Placed a total of 77,800 lbs of proppant into the formation. Rigged down. 10/31/93: RIH w/CT & jetted a proppant fill cleanout to 10125' MD, to uncover the open perforations (above). I I /2/93: RIH & tagged bottom proppant fill at 10065' MD. Returned the well to production w/gaslift & obtained a valid welltest. ARCO Alaska, Inc. P.O.Box 1OO360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOLE FINALS ~.._~~L_l-30 1-31-93 ~} ~.~ ~l_..~..._~- 11 1-4-93 1-10-93 ~---"~-----..~-1 )~ * ~-o- 13 1-11-93 ~0.~._~ -32 11-12-92 11-S-92 ~-6 11-28-02 1-29-93 11-15-92 11-19-92 1-27 11-6-92 11-27-92 I 11-18-92 1-2-93 1-1-93 2-1-93 ffZ-1 1-9-93 1-18 11-18-92 2-10A 11-15-92 4-7 1-3-93 ~4-7 1-8-93 ~..~..~_~14-15 11-2-92 ~~4-22 11-16-92 4-22A 1-8-93 4-43 11-14-92 12-2-92 16-25 11-29-92 ~6-28 12-31-92 Q0 .,1~ ~"'~~6-29A 6-30 11-29-92 1-5-93 q~~.~17-19 11-17-92 Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record DSN Perf Record Collar'(Inflatable Packer) Collar (To spot Jet cutter] Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Perf Record Please sign and return the attach~ copy as receipt of data. Have A Nice Day~ Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1, R~ 1. R~ 1, Sonya Wallace ATO-1529 HIS HIS HIS HIS HIS HIS HLS HIS HLS HIS HIS HIS HL8 HL8 HIS HL8 HIS HLS HIS HL8 HIS HIS HIS HIS HIS HLS HLS HIS HIS HIS HIS RECEIVED # PHILI.i~ PB~FII2~ #BPX # STATE OF ALASKA These logs were mn in 1993 not 1992. The correct APl# for 4-14A is 50-029-2031~. The correct APl# f~r 16-29A is 50-029-22272-01. Alaska Oil & Gas Cons. Commls$1or~ ARCO Ahska, Inc. P.O.Box 100360 Anchorage, ~l_-_,k~ 99510 DATE: 11-13-92 REFERENCE: ARCO DIRECTIONAL DATA -~--~~4-14A Il-lA ~12-10A q ~.~~--~14-41 7-15 10-18-92 10-30-92 10-26-92 10-27-92 10-9-92 10-14-92 10-29-92 10-14-92 10/19-31/92 10-3-92 MWD Directional Survey MWD Directional Survey MWD Directional Survey Electronic Survey System MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey Please aign and return/the atta?ed copy as receipt of data. Have A Nice Day~" -~-'~----~--- ~onya Wallace ATO- 1529 Speny SperrF Teleco Teleco APPROVED___~ Tr~_ns# 92252 CENTRAL FILES CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON MOBIL # PB WELL FILE~ R&D #BPX # ST. OF AIL (2 COPIES) i ALASKA'/~""i, AND GAS CONSERVATION CC"~:'/IlSSION REPORT SUNDRY WELL OPL,;ATIONS ' 1. Operations performed: Operation shutdown , Stimulate X Plugging Perforate X , Pull tubing ~ Alter casing --... Repair well Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 768' NSL, 733' EWL, Sec. 18, T10N, R15E, UM At top of productive interval 1860' SNL, 1684' EWL, Sec. 19, T10N, R15E, UM At effective depth At total depth 2000' SNL, 1908' EWL, Sec. 19, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 10305 feet 9131 feet 5. Type of Well Development X Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-10A 9. Permit number/approval number 92-89 10. APl number 50 - 029-20586-01 11. Field/Pool Prudhoe Bay Oil Pool Plugs(measured) Fill @ 10008' MD (11/18/92) Effective depth: measured 10008 feet true vertical 8903 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 110' 20" 232 sx AS II 110' Surface 2571' 13-3/8" 2700 sx Fondu & 400 sx PF II 2642' Production 7334' 9-5/8' 500 sx Cl G 7405' Liner 3128' 7" 140 cu ft Cl G 10305' feet True vertical depth 110' 2642' 6933' 9131' Perforation depth: measured 10070-10090' true vertical 8951-8966' Tubing (size, grade, and measured depth) 4-1/2", 12.6g, 13 CR 80, Tbg @ 9740' MD RECEIV i) Alaska Packers and SSSV (type and measured depth) 7", Otis MHR Packer @ 9672' MD; Camco TRSV @ 2050' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 0 0 0 -- Tubing Pressure 0 ., Subsequent to operation 5388 ~'- 4551 907 -- 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run i Daily Report of Well Operations ..__ Oil X Gas ,~. Suspended .__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ Title Engineering Supervisor Form 10-404 Rev 06/15/88 938/14 DTK cc: SW, JWP 326 Date SUBMIT IN DUPLICATEq~ 12-10A DESCRIPTION OF WORK COMPLETED ROPE PERFORATING & FRACTURE TREATMENT OF ZONE 4 I I/6/92: RIH & tagged bottom at 10249' MD. I I/1 5/92: MIRU & PT equipment. RIH w/perforating gun & logged into position. Pumped 63.5 bbls of Seawater w/friction reducer, down the tubing & pressured up to 6600 psi, to perform a ROPE (Really Overpressured Perforation Extension) Treatment, then shot initial perforations at: 10070 - 10090' MD (Z4) POOH w/perforating gun. All shots fired. 1 I/1 7/92: Ref. Log: BHCS Rigged down. 10/28/92. MIRU & PT to 9500 psi. Pumped a Hydraulic Fracture Treatment, using 16/20 mesh proppant, through the perforations (listed above). Pumped: a) 250 bbls Pre Pad @ 30 bpm, followed by b) Shutdown. Resumed pumping Data Frac: c) 100 bbls Crosslinked Gel @ 30 bpm, followed by d) 96 bbls Gelled Flush @ 5 bpm gradually increased to 30 bpm, followed by e) Shutdown. Resumed pumping Frac: f) 40 bbls 40# Crosslinked Pad @ 30 bpm, followed by g) 251 bbls Slurry w/proppant stages @ 1 - 10 ppg, followed by h) 151 bbls 20# Gelled Flush, followed by i) Shutdown. Placed a total of 56,700 lbs of proppant into the formation. Rigged down. I I/1 8/92: RIH & tagged top of proppant fill at 10008' MD. Placed well on production with gaslift and obtained a valid welltest. STATE OF ALASKA ALASKA ~,IL AND GAS CONSERVATION CO,v,MISSIONn WELL COMPLETION OR RECOMP LETION REPOR? J l{l[ L 1. Status of Well Classificalion of Service Well OIL [] GAS [] SLE, PENDED [] ABANDONED [] SERVICE [] 2. Name of Operator ..... 7. Permii Number ARCO Alaska, Inc. 92-89 3. Address 9. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20586-01 4. Location of well at surface 19. Unit or Lease Name 768' NSL, 733' EWL, SEC. 18, TION, R15E :;~ ~"'~ ...... ~ ~ ~ ~ LOC~'~'t~;'J' i Prudhoe Bay Unit 1860'SNL, 1684'~Wl., SEC. 19, TION, R15~, UM!' ~:!~:ir~ ~ DS 1£-10A At Total Depth }i..~ ........... ~: ~. 11. Field and Pool ,~ ...................... ~- ".~.~.,~ -~., ? Prudhoe Bay Field/Prudhoe Bay Pool 2000'SNL, 1908'EWL, SEC. 19, TION, R15E, UM 5. Elevation' in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. KBE=71' I ADL 28330 12. Date Spudded 113. Da~e T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore ' 116. No. of CompletiOns 10/16/92 10/27/92 11/15/92I N/A feet MSL I One.. 17. Total Depth iMD+TVD} 118. Plug Back Depth (M'D+TVD; 19. Directional' Survey FO. Depth where SSSV set Fl. Thickness of Permafrost 10305' MD/9130' TVD 10262' MD/9098' TVD YES [] ND []! 2050'feet MD ! 1900' (Approx.) 22. Type Electric or Other Logs Run D L L /G R/A C/M L L/M WD 23. "" CASING, LINER AND CEMENTING ~ SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEM~ RE-CORD AMOUNT PULLED ,,, 20" 94~ H-40 Surface 110' 30" 232 sx AS II 13-3/8" 72# N-80 SUrface 2642' 17-1/2" 2700 sx Fondu & 400 sx PF I 9-5/8" 47# L80/S0095 Surface 7405' 12-1/4" 500 sx Class "G" 7" 26# 13CR/L80 7194' 10305' 8-1/2" 140 cufl Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and !25. TUB~RECORD interval, size and number) '" SIZE D~PTH SET(MD) PA~KER SET (MD) Gun Diameter 2-1/2" 4 spf 4-1/2", 13CR80 9740' 9672' MD TVD 10070'-10090' 8951:8966' 26. ACID, FRACTURE, CEMENT SQUEF-'TF, ETC. DEPTH 'INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7350;7505' Kickoff Plug, 365 cufl Class "G" cmt. Hesitation squeezed to 2000 psi ,, 27. PRODUCTION TEST !'Dat~ First Production IMethod of Operation ('Flowing, gas lift, etc.) 11/21/92 I Gas Lift 'bat~" of Test Hours' Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL. RATIO TEST PERIOD ~ I FIo~ Tubing Casing Pressure 3ALCULATED OII'-BBL GAS-MCF WATER-BBL OIL 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. Form 10-407 Rev. 7-1'80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS , _,-{MATION TESTS NAME Include interval lesled, pressure data, all fluids recovered and gravity, ME. AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Shublik 10206' 8982' Top Sadlerochit 10063' 8874' 31. LIST OF ATTACHMENTS ,, 32. I hereby certify that the fore oing is true and correct to the best of my knowledge Signed ~ ).., Title Drilling Engineer Supervisor 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/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 12-10A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 10/13/92 09:10 SPUD: 10/18/92 07:10 RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 10/14/92 ( 1) TD: 0 PB: 0 10/15/92 ( 2) TD: 0 PB: 9270 10/16/92 (3) TD: 0 PB: 7605 10/17/92 ( 4) TD: 0 PB: 7605 10/18/92 ( 5) TD: 0 PB: 7345 10/19/92 (6) TD: 7404' (7404) . MW: 0.0 MOVE RIG F/DS 12-22 TO DS 12-10A, SPOT & LEVEL RIG OVER WELL, TAKE ON SEAWATER IN PITS, SPOT TANKS, PUMP OPEN ACTUATOR VALVE ON TREE, RU LUBRICATOR, CIRC WELL TO 8.5 PPG SEAWATER, CIRC THRU CHOKE TIL WELL STABLE, ATTEMPT TO INSTALL BPV, WILL NOT SEAT IN TBG HGR PROFILE, DSM, ATTEMPT TO INSTALL REDRESSED BPV @ REPORT TIME POH, L/D 5-1/2" TBG MW: 0.0 SET BPV W/HI-PRESSURE DSM, R/D LUBRICATOR, N/D TREE & ADAPTOR FLANGE, U/U BOPE, INSTALL 3RD SGL. GATE, TEST BOPE, TEST BLINDS OK, PULL TREE TESTER VALVE & BPV, M/U LND JT, 3-1/2" X 6"VBR LEAKED, CHG TO SOLID 5" PIPE RAMS, WILL NOT HOLD SOLID 5000 PSI, LEAKING BY TBG HGR, BOLDS, PULL TBG FREE @ 175K, PULL TBG HGR TO FLOOR, TOP SEAL MISSING, CBU, WELL STABLE, R/U TO PULL C/L, PULL 5-1/2" TBG & LAY DOWN SAME RIH W/SECTION MILL MW: 0.0 L/D 5-1/2" TBG, INSTALL TEST PLUG, TEST BOPE, MU BRIDGE PLUG & RIH, SET @ 7605', DISPLACE WELL TO KCL/POLYMER MILLING FLUID, POH, SLIP & CUT DRLG LINE, MU BHA W/SECTION MILL, P/U MWD TOOL, SURFACE TEST MWD - OK, RIH W/SECTION MILL CLEAN HOLE. MW: 9.8 KC1 RIH W/ SECTION MILL. SPOT 18 PPG PILL ON 9-5/8" BP @ 7605' POOH TO 7345' MILL SECTION F/ 7345'-7405' CIRC. N/U BOPE. MW: 9.7 KC1 CIRC. POOH. L/D BHA. RIH W/ MULE SHOE TO 7505'. CBU. REV CIRC. PUMP 32 BBLS WATER, 65 BBLS 17 PPG CMT. DISP W/ MUD. POOH 15 STDS. SQZ CMT W/ 2000 PSI. SQZ'D 20 BBLS CMT. POOH. N/D BOPE. KICKOFF HOLE. MW: 9.6 VIS: 55 TEST BOPE. RIH W/ DRLG BHA. REAM THRU CMT STRINGERS F/ 7019'-7178'_ DRLG CMT F/ 7178'-7350'. KICKOFF WELL THRU WINDOW. SpUD S/T @ 19:30 HRS, 10/18/92. WELL : DS 12-10 OPERATION: RIG : DOYON 16 PAGE: 2 10/20/92 (7) TD: 7875' ( 471) 10/21/92 (8) TD: 8076' ( 201) 10/22/92 ( 9) TD: 8525' ( 449) 10/23/92 (10) TD: 9190' ( 665) 10/24/92 (11) TD: 9383' ( 193) 10/25/92 (12) TD: 9752' ( 369) DIRECTIONAL DRILL 8-1/2" HOLE MW: 9.8 VIS: 51 DIRECTIONAL DRILL 8-1/2" HOLE, SLIDE & ROTATE EVERY OTHER SGL FOR KO & DIRECTIONAL CONTROL F/7404'-7875' TRIP FOR BIT MW: 9.8 VIS: 53 DIR DRILL F/7875' TO 8060', CIRC, HI/LOW VIS SWEEP, HOLE CLEAN, DROP MULTI SHOT, POH FOR PDC BIT, RETREIVE SURVEY, L/D BIT & DYNADRILL, P/U HYCALOG PDC BIT CHG OUT STABILIZER SLEEVE TO DYNA DRILL PDM, RIH W/BHA # 3, DRLG F/8060(ROP 7-9'/HR), TROUBLE SHOOT ROP, CIRC HOLE WHILE MIXING DRY JOB, POH F/BIT CHG DRLG 8-1/2" TANGENT SECT. MW: 9.8 VIS: 54 COMPLETE POH F/SMITH M943 PDC BIT, RIH TO 9-5/8" SHOE @ 7350', FILL UP DP, RIH TO 8017', REAM/WASH F/8017' TO 8076', DRILL TO 8525' DRILLING 8-1/2" TANGENT SECT. MW: 9.8 VIS: 54 DRILL F/8525'-8710', CIRC. HIGH/LOW VIS SWEEP, SHORT TRIP 10 STDS TO 9-5/8" SHOE @ 7435', MAX DRAG OBSERVED=25 KIPS ABOVE NORMAL PU WT., RIH, KELLY UP, WASH/REAM 43' TO BOTTOM @ 8710', DRILL F/8710'-9190' DRLG 8-1/2" TANGENT SECTION MW: 9.9 VIS: 58 DRILL F/9187-9190, DYNADRILL ROTOT FAILURE, CIRC, HI/LO VIS SWEEP, DROP SURVEY, 'PUMP DRY JOB, POH, PU NEW DYNADRILL & PDC BIT, C/O LEAD COLLAR & STAB, RIH & FUNCTION TEST MWD, CUT & SLIP DRILG LINE, FILL PIPE @ 9-5/8" SHOE, REAM F/9150' TO 9190', DRILL TO 9383' DRLG 8-1/2" TANGENT SECTION DRILL F/9383' TO 9752' MW: 9.9 VIS: 68 10/26/92 (13) TD: 9953' ( 201) 10/27/92 (14) TD:10250' ( 297) RIH W/BHA #6 MW: 9.9 VIS: 68 DRILL F/9752'-9766' PUMP SWEEP, PUMP DRY JOB, KELLY BACK, POH SHORT TRIP TO 9~5/8'' SHOE @ 7345', RIH TO 9722', KELLY UP, CIRC/REAM DELLY DOWN TO 9766',. DRILL TO 9953', CIRC HI/LO VIS SWEEP, DROP SINGLE SHOT SURVEY, POH F/BHA CHG, M/U BHA #6, RIH W/BHA #6 DRILLING SADLEROCHIT ZULU/VICR DRILL 8-1/2 HOLE TO 10250' MW:10.2 VIS: 59 10/28/92 (15) TD:10305' ( 55)' RIH. MW:10.2 VIS: 54 DRLG TO 10305' CIRC. SHORT TRIP TO SHOE. CIRC. POOH. R/U ATLAS. LOG RUN: DLL/GR/AC/MLL. R/D ATLAS. RIH W/ BHA. WELL : DS 12-10 OPERATION: RIG : DOYON 16 PAGE: 3 10/29/92 (16) TD:10305' ( 0) 10/30/92 (17) TD:10305' ( 0) 10/31/92 (18) TD:10305 . . PB:10262 11/01/92 (19) TD: 10305 PB: 10262 11/02/92 (20) TD: 10305 PB:10262 CMT 7" LINER · MW:10.2 VIS: 56 RIH BRIDGE @ 10096', REAM 10096'-10305', CIRC & COND PUMP AROUND SWEEP, POH' LD 86 JTS DP & 18 HWDP & 8.5 BHA, CLEAR FLOOR OF BHA, RIG UP TORQUE TURN & RUN 7" CR LINER, R/U BAKER PKR & CIRC PIPE VOL, RIH W/LINER ON 5" DP TO 9-5/8" SHOE @ 7345', CIRC LINER, P/U BAKER CMT HEAD, RIH W/7" LINER TO 10305', CIRC. PUMP ARCO SWEEP, TEST CMT LINES TO 3000 PSI & CMT AS PER PROGRAM DRLG CMT @ 10125' MW:10.2 VIS: 60 CMT DISPLACED W/RIG PUMP, DID NOT'BUMP PLUG, POH, L/D RUNNING TOOLS, MU 8.5" BIT & 9-5/8" CSG SCRAPER, RIH TO LINER TOP @ 7173', SERVICE RIG & PUMP, CBU, DRY JOB, POH, L/D SCRAPER, P/U LINER POLISH MILL, RIH TO LINER TOP, KELLY UP PLR TO 7178', POH, R/U SEAL ASSEMB, RIH, STING IN PRESSURE TO 4000 PSI, SET PKR TEST LAP TO 3500 PSI, POH, L/D SEAL ASSEMB, P/U 6" BHA CU DRLG LINE, RIH TO 10125' TOP CMT, DRLG CMT POH, L/D DP MW: 9.7 KC1 DRILL CMT TO 10262' (LNDG COLLAR), CIRC HOLE CLEAN, DRY JOB, POH, RIH W/7" SCAPER, CIRC, CLEAN PITS, TAKE ON SEAWATER, DISP. HOLE TO SEAWATER, POH-LDDP TO 9800', CIRC & INHIBIT SEAWATER W/C193, POH-LDDP, TEST CSG TO 3500 PSI W/SEAWATER, TRIP OUT L/D DP R/U TORQUE TURN L/D LDG-SET BV MW: 9.7 KC1 L/D DP, DC & SCRAPER, PULL WEAR BUSHING R/U TORQUE TURN & OTIS, SERVICE RIG, RUN 4-1/2" PROD. STRING, 13CR80 TDS, P/U CAMCO TRSV, RUIH, M/U TBG HGR & TEST, PRES. TBG TO 4200 PSI, SET PKR, TEST TBG ANNULUS TP 2500 PSI-30 MIN, R/D OTIS & TORQUE TURN, L/D LDG JT, SET BPV RIG RELEASED 11/1 12:00 MW: 9.7 KC1 N/D BOPE, RUN CONTROL LINE & TEST, N/U TREE, TEST ADAPTOR FLANGE & TREE TO 5000 PSI, PULL BPV PRESS TEST TBG TO 1000 PSI, SHEAR OUT RP @ 2900 SPI, PUMP 135 BBLS DIESEL DOWN ANNULUS, U-TUBE TO TBG, SET BPV, RELEASE RIG TO MOVE @ 12:00 HRS 11/1/92 SIGNATURE: (drilling superintendent) DATE: PA~£ NO. *********************************************** ***~***** ANAD~ILL *************************************************** W~LL HEAD LOCATION: LAT(N/-S) 0.00 AZi~kF~H FR~ E~TARY TABLE TO TA~ET IS TIE IN POINT(TIP) : ~U~ V~2 DEPTH I~LINATI~< AZiML~H LATITLID~(N/-S? D~PARTUR£(E/-W) 7350.00 40.12 130,08 -959.00 DEF'(E/-W) 0o00 178.55 MICI OFILMED 2 F£~$L~:ED INTE;,~AL V~T!CAL DEP?H DEF:TH ft ft f? 7350,00 0.0 6891 o~.~ Z~,4 7100,0~: 7657.0~ 31,7 7123,34 7~,.6~ 3!.6 7!46,67 *********~*** ANA~RILL ************** SLtRV~9' CA~ULAT!ONS ****** MINIMUM ?A~FT S~ATI~ AZi~;~ ~TITLIDE SE~iON iNCLN, E/-S ft deg deg ft 507,69 40,12 !30,08 -~9,00 616,~ 42,63 162,5i -1106,79 634.62 42,57 165.91 -I127,4i 652,91 42,3i 169.~. -1148,23 670,95 42,17 171,89 -1}EJ,37 7748,8~ 7780.I9 78il,65 7843.12 7874,60 29.8 7191,30 3i.4 ,.'~l~,..~ ~1,~ 7238.15 3i.5 72~i~64 31.5 7285,02 68.6.94 41,96 173,59 -11~8,19 707,¥~ 4i,72 173,87 - ~ 727.22 41,68 1779,89 -1229,85 746,66 4i,70 17~,73 -1250,76 766,~ 42,39 181,22 -1271,85 7906,26 7937.43 7967,82 79'?6.9i 809!,~3 31,7 73O8,43 3!.2 733t,52 ~:,.4 7354,12 3!,1 7377.38 92,i 7446,81 767.32 42,28 183,53 -1293,15 807,69 42,12 187,04 -13i3,99 827.~ 4t,79 188,92 -1334.11 848,C~, 4i,~ i91,~n~ -1354.41 906,26 40.76 193,67 -i413,43 8183,54 8275,7~ 83.68.99 846t.80 8555,02 92,5 7516,9K o~.~.3 ~86,97 93,2 7657.81 92.~= 772~,39 ~:,2 7799.~ 968,43 4(:,68 194,14 -1472,03 1028.28 40,~ 193,62 -15~.33 108~,~J 40,51 193,71 -1589,18 1148,72 40,49 194.48 -1647,63 1208,99 40,37 193,55 -1706,29 8836,84 8929,76 9023,21 94.2 767i,14 '~,3 7942,~ 94.3 8014,3'7 92.9 8085,6f. 93,4 81¢5,.z 1269.78 40,33 194.03 -1765.53 l~?.t2 40,25 194,02 -1824.0~. 1.39.'0,56 40,04 194,78 -18S2.'.;5. 1450.82 40,95 196.26 -1941,09 151t.&B 41,02 191.~° -20C0.51 9116.53 9210.~ 9~31,0! 9394._W 9487.44 93.3 8226,%5 94,0 8298,22 93,6 643~,75 1572,24 40,02 194,6S' -2059,51 1632,97 40,69 194,57. -2118.42 1691,40 39,90 197,00 -2174.71 1,~1.70 40,~? 200,16 -2231,87 1812,(X~ 40,68 201.~5 -22&5,25 9579,68 9674,00 9767,87 9855,97 92,4 8~9,16 94,! 8649.75 93,9 67i9,73 92,1 8788.18 1872,46 41,21 202.84 -2344.32 19~.~, 4i,60 201,97 -2401,66 19%,93 41,?? 203.94 -2459.47 2056,20 42.0! 205,56 -2515,49 I)S J 2-1 OA DEPARTURE DISF'LAT;EMEHT at E/-W ft ft 1262,00 1585.03 1359,05 1752,7! 1'364,86 1770,29 1369,44 1787,12 1372,76 1802.65 AZIML~H deo 127~23 129,i6 129,%~. 129,98 1~J,40 13/5,29 1817,48 130,83 1377,57 1832,85 131,27 !379,07 1847,80 131.73 1379.69 1862,25 132,19 1379,70 1876,48 132,67 1378,82 1890,33 133,16 1376,8¢' 1903,26 133,&5 1374,07 19!5,18 134,15 1370,38 1926,75 134,d~, I~7,10 1959,47 136,16 1~2.60 17?2,35 137,63 1328,19 2026.33 139,04 13i3.88 20~,i,98 140,42 1299,20 ~[)98,24 141,74 121~.54 2135,76 143,03 i2.%',99 2174,84 144,27 14~.4,., 1255,37 2214,~' ~ ~ 1240,2'5 2254,71 146,63 12.2'4,0~ 2294,82 147,76 1209.23 2337,58 148,85 11~,35 ~I,27 14?,67 1179.97 2424,88 150,86 llg,07 24,~,.66 151,84 1144.85 2508,37 152,84 1123,31 2549,10 153,85 110,3,38 2589,72 154,86 107~.6.5 2632,13 155.86 1052,25 2675.11 156,84 deg/ lOOft 0.00 7,78 7,27 7,46 5.57 3,88 0,97 8,50 1.7/:., 5,75, 4,9t 7,5g 4.29 6,06 1,56 0,34 0,39 0,08 0,54 0,64 0.31 0,09 0,56 1,42 3.I2 2.27 0,72 ! ,95 2,24 1,09 1,02 0,74 1.45 1,1e ~:"*~RRY-SUN DRILLING SERVICEF--~' ANCHORAGE ALASKA PRUDHOE BAY DRILLING PBU/12-10A . _.. 500292058600 NORTH SLOPE COHPUTATION DATE' 11/03/9Q~ 16 ! N A £ DATE OF SURVEY: 10/27/92 ELECTRONIC SURVEY SYSTEM JOB NUMBER: AK-EI-20084 KELLY BUSHING ELEV. = 22.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA COURS HEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS DIRECTION DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 7350 6891.00 6869.00 40 5 7500 7006.51 6984.51 40 34 7595 7077,88 7055.88 42 10 7688 7146.25 7124.25 42 5 7782 7216.99 7194,99 41 27 S 49.90 E . O0 S 31.30 E 7.96 S 19.27 E 8.53 S 10,16 E 6,63 S 3.93 E 4.43 959.00S 1262.00E 1304.29 1032.55S 1324.93E 1393,77 1089,13S 1351,54E 1455,83 1148,75S 1367.21E 1517.36 1211.35S 1374.97E 1579.27 7876 7286.90 7264,90 42 13 7971 7357.63 7335.63 41 22 8062 7426.43 7404.43 40 43 8155 7497.18 7475,18 40 36 8248 7567,62 7545.62 40 29 S 2.65 W 4.75 S 9.65 W 4,99 S 14.23 W 3.38 S 14.33 W .13 S 14.10 W ,21 1273.85S 1375.64E 1638.87 1336.63S 1368.90E 1696,43 1395.20S 1356.53E 1748.24 1454,10S 1341.54E 1799,54 1512.53S 1326,74E 1850,46 8342 7638.87 7616.87 40 23 8434 7709.48 7687.48 40 20 8528 7781,00 7759,00 40 14 8623 7853,32 7831.32 40 6 8718 7925.92 7903,92 39 59 S 14.42 W .24 S 14.00 W .30 S 13.96 W .11 S 14,32 W .28 S 14.82 W .37 1571,38S 1311,78E 1901.72 1629,56S 1297,05E 1952,42 1688.40S 1282,40E 2003.78 1747.61S 1267.48E 2055.40 1806.67S 1252.13E 2106.74 8812 7998.18 7976.18 39 51 S 15.13 W .25 8906 8069.80 8047.80 40 26 S 16.15 W ,93 8998 8139.94 8117.94 40 58 S 15.93 W ,60 9093 8211.95 8189.95 40 5 S 15.08 W 1,11 9187 8284.25 8262,25 40 9 S 14,54 W ,38 1865,09S 1236.50E 2157.39 1923.27S 1220.21E 2207.61 1981,28S 1203.54E 2257.54 2040,60S 1187.08E 2308.78 2099.50S 1171.50E 2359.91 9279 8354.11 8332.11 40 5 S 17.57 W 2.14 9372 8425.18 8403.18 40 2 S 20.00 W 1,68 9465 8496.21 8474.21 40 15 S 21.75 W 1.24 9558 8566.97 8544.97 40 53 S 21.57 W .69 9652 8638,01 8616.01 41 31 S 22.78 W 1,08 2156.06S 1155,22E 2408.59 2212.64S 1135.97E 2456.36 2268.63S 1114,61E 2502.91 2324.96S 1092.24E 2549.48 2382.57S 1068,75E 2596.91 9747 8708,79 8686.79 41 55 S 23.83 W .84 9840 8778.29 8756.29 41 53 S 25.52 W 1.20 9935 8848,94 8826,94 41 46 S 27.72 W 1.55 10030 8920.19 8898,19 40 32 S 27,34 W 1.33 10121 8989,81 8967.81 40 4 S 27.07 W ,55 2440,53S 1043.77E 2644.21 2497.20S 1017,74E 2689.96 2553,71S 989,42E 2734.84 2608,94S 960.64E 2778.36 2661.45S 933.64E 2819.86 10215 9061.88 9039.88 39 42 S 26.16 W ,73 2715,31S ' 906.66E 2862.63 10251 9089.55 9067,55 39 50 S 26.22 W .41 2735.97S 896.50E 2879.11 THE CALCULATION PROCEDURES ARE BASED ON THE U~EOF~iV~D THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2879.11 FEET " AT SOUTH 18 DEG. 8 MIN. EAST AT MD = 102~ 09 1993 L8A~$~ OU&Gas~ns.~mm~n VERTICAL SECTION RELATIVE TO WEL HEAD Ancho~ VERTICAL SECTION COMPUTED ALONG 161. 6 DEG. ~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGb PRUDHOE BAY DRILLING PBU/12-10A .... 500292058600 NORTH SLOPE COMPUTATION DATE: 11/ 3/92 DATE OF SURVEY: 102792 JOB NUMBER: AK-EI-20084 KELLY BUSHING ELEV. = 22.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINAT DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WE ES MD-TVD VERTICAL ST DIFFERENCE CORRECTION 7350 6891.00 6869.00 959.00 S 1262,00 E 459.00 8350 7644.74 7622.74 1576.22 S 1310,54 E 705°26 246.26 9350 8408,18 8386,18 2199,22 S 1140,86 E 941.82 236.56 10251 9089.55 9067,55 2735.97 S 896.50 E 1162,07 220,26 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ,~o-¢'"'~"RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY PBU/12-10A 500292058600 NORTH SLOPE COMPUTATION DRILLING _o - DATE: 11/ 3/92 DATE OF SURVEY: 102792 JOB NUMBER: AK-EI-20084 KELLY BUSHING ELEV. = 22.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH NEASD DEPTH TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH NORTH/SOUTH EAST/NEST ND-TVD VERTICAL DIFFERENCE CORRECTION 735O 7390 7521 7655 6891.00 6869.00 959.00 S 1262.00 E 6922.00 6900.00 976.60 S 1281.14 E 7022.00 7000.00 1044.13 S 1331.53 E 7122.00 7100.00 1127.35 S 1362.70 E 459.00 468.47 9.47 499.42 30.96 533.39 33.97 7789 7923 8O56 8188 8320 7222.00 7200.00 1215.78 S 1375.25 E 7322.00 7300.00 1305.33 S 1373.19 E 7422.00 7400.00 1391.49 S 1357.44 E 7522.00 7500.00 1474.73 S 1336.28 E 7622.00 7600.00 1557.48 S 1315.36 E 567.54 34.15 601.86 34.32 634.85 32.98 666.67 31.82 698.14 31.47 8451 8582 8713 8843 8974 7722.00 7700.00 1639.88 S 1294.48 E 7822.00 7800.00 1722.04 S 1274.00 E 7922.00 7900.00 1803.49 S 1252.97 E 8022.00 8000.00 1884.29 S 1231.31 E 8122.00 8100.00 1966.29 S 1207.81 E 729.39 31.25 760.42 31.04 791.10 30.68 821.48 30.37 852.92 31.44 9106 9237 9368 9498 9631 8222.00 8200.00 2048.77 S 1184.88 E 8322.00 8300.00 2130.27 S 1163.31 E 8422.00 8400.00 2210.13 S 1136.89 E 8522.00 8500.00 2288.92 S 1106.52 E 8622.00 8600.00 2369.50 S 1074.24 E 884.56 31.64 915.36 30.80 946.05 30.68 976.93 30.89 1009.36 32.42 9765 9899 10032 10163 10190 8722.00 8700.00 2451.38 S 1038.98 E 8822.00 8800.00 2532.41 S 1000.61 E 8922.00 8900.00 2610.31 S 959.92 E 9022.00 9000.00 2685.57 S 921.33 E 9042.17 9020.17 2700.61 S 913.88 E 1043.33 33.97 1077.65 34.32 1110.79 33.14 1141.75 30.97 1147.83 6.08 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SP~-~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PRUDHOE BAY PBU/12-10A 500292058600 NORTH SLOPE COMPUTATION DRILLING DATE' 11/03/92 ORIGI A DATE OF SURVEY: 10/27/92 ELECTRONIC SURVEY SYSTEM JOB NUMBER: AK-EI-20084 KELLY BUSHING ELEV. = 22.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DLS TOTAL RECTANGULAR COORDINATES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 7350 6891,00 6869.00 40 5 S 49,90 E 7500 7006.51 6984.51 40 34 S 31.30 E 7595 7077,88 7055,88 42 10 S 19.27 E 7688 7146.25 7124.25 42 5 S 10.16 E 7782 7216.99 7194.99 41 27 S 3.93 E .00 959.00S 1262,00E 7.96 1032,55S 1324.93E 8.53 1089.13S 1351.54E 6.63 1148.75S 1367.21E 4.43 1211.35S 1374.97E 1304.29 1393.77 1455.83 1517.36 1579.27 7876 7286.90 7264.90 42 13 S 2.65 W 4.75 7971 7357.63 7335.63 41 22 S 9.65 W 4,99 8062 7426.43 7404.43 40 43 S 14.23 W 3,38 8155 7497,18 7475,18 40 36 S 14.33 W ,13 8248 7567,62 7545.62 40 29 S 14.10 W ,21 1273.85S 1375,64E 1336.63S 1368.90E 1395.20S 1356.53E 1454,10S 1341.54E 1512.53S 1326.74E 1638.87 1696.43 1748.24 1799.54 1850.46 8342 7638,87 7616.87 40 23 S 14.42 W ,24 8434 7709.48 7687.48 40 20 S 14.00 W .30 8528 7781.00 7759.00 40 14 S 13,96 W .11 8623 7853.32 7831.32 40 6 S 14.32 ~ .28 8718 7925.92 7903.92 39 59 S 14.82 W .37 1571.38S 1311.78E 1629.56S 1297.05E 1688.40S 1282.40E 1747.61S 1267.48E 1806·67S 1252,13E 1901,72 1952.42 2OO3.78 2055.40 2106.74 8812 7998.18 7976.18 39 51 S 15.13 W .25 8906 8069,80 8047,80 40 26 S 16.15 W .93 8998 8139.94 8117,94 40 58 S 15,93 W .60 9093 8211.95 8189.95 40 5 S 15.08 W 1.11 9187 8284.25 8262.25 40 9 S 14,54 W .38 1865.09S 1236.50E 1923.27S 1220.21E 1981.28S 1203.54E 2040.60S 1187.08E 2099.50S 1171.50E 2157.39 2207.61 2257.54 23O8.78 2359.91 9279 8354.11 8332.11 40 5 S 17.57 W 2.14 9372 8425.18 8403.18 40 2 S 20.00 W 1.68 9465 8496.21 8474.21 40 15 S 21.75 W 1.24 9558 8566.97 8544.97 40 53 S 21.57 W ,69 9652 8638,01 8616.01 41 31 S 22.78 W 1.08 2156.06S 1155.22E 2212.64S 1135.97E 2268.63S 1114.61E 2324,96S 1092,24E 2382.57S 1068.75E 2408.59 2456.36 2502.91 2549.48 2596.91 9747 8708,79 8686.79 41 55 S 23.83 W .84 9840 8778.29 8756.29 41 53 S 25.52 W 1.20 9935 8848.94 8826,94 41 46 S 27.72 W 1.55 10030 8920.19 8898.19 40 32 S 27,34 W 1.33 10121 8989.81 8967.81 40 4 S 27.07 ~ .55 2440.53S 1043.77E 2497.20S 1017·74E 2553,71S 989,42E 2608.94S 960.64E 2661.45S 933.64E 2644.21 2689.96 2734.84 2778.36 2819.86 10215 9061.88 9039.88 39 42 S 26.16 W .73 2715.31S 10251 9089.55 9067,55 39 50 S 26,22 W .41 2735.97S 906.66E 2862.63 896.50E 2879.11 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD· HORIZONTAL DISPLACEMENT : AT SOUTH 18 DEG. 8 MIN. 2879.11 FEET EAST AT MD = 10251 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 1 6 1 86 Sf~RY-SUN DR]:LL:[NG SERVICES ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRZLLZNG PBU/12-10A 500292058600 NORTH SLOPE COMPUTATZON DATE: 11/ 3/92 DATE OF SURVEY: 102792 JOB NUMBER: AK-EZ-20084 KELLY BUSHING ELEV. = 22.00 OPERATOR: ARCO ALASKA INC FT. ZNTERPOLATED VALUES FOR EVEN 1000 FEET OF NEASURED DEPTH TRUE SUB-SEA TOTAL NEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 7350 6891.00 6869.00 959.00 S 1262.00 E 459,00 8350 7644,74 7622.74 1576.22 S 1310.54 E 705.26 9350 8408,18 8386.18 2199,22 S 1140.86 E 941.82 10251 9089.55 9067.55 2735.97 S 896.50 E 1162.07 246.26 236.56 220.26 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD, S~"~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRILLING PBU/12-10A 500292058600 NORTH SLOPE COMPUTATION DATE: 11/ 3/92 DATE OF SURVEY: 102792 JOB NUMBER: AK-EI-20084 KELLY BUSHING ELEV. = 22.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 7350 6891,00 6869.00 959.00 S 1262.00 E 459,00 7390 6922,00 6900.00 976,60 S 1281.14 E 468,47 7521 7022,00 7000.00 1044.13 S 1331.53 E 499,42 7655 7122.00 7100,00 1'127.35 S 1362.70 E 533.39 9.47 30.96 33.97 7789 7222.00 7200,00 1215.78 S 1375.25 E 567.54 7923 7322.00 7300,00 1305.33 S 1373,19 E 601.86 8056 7422.00 7400.00 1391,49 S 1357,44 E 634.85 8188 7522.00 7500,00 1474.73 S 1336.28 E 666.67 8320 7622,00 7600,00 1557,48 S 1315.36 E 698.14 34.15 34,32 32.98 31.82 31.47 8451 7722,00 7700.00 1639.88 S 1294.48 E 729.39 8582 7822,00 7800.00 1722.04 S 1274.00 E 760,42 8713 7922.00 7900,00 1803.49 S 1252.97 E 791.10 8843 8022.00 8000,00 1884.29 S 1231.31 E 821.48 8974 8122.00 8100.00 1966.29 S 1207.81 E 852.92 31 .25 31 .04 30.68 30.37 31 .44 9106 8222.00 8200,00 2048.77 S 1184.88 E 884.56 9237 8322,00 8300.00 2130.27 S 1163.31 E 915.36 9368 8422.00 8400,00 2210,13 S 1136.89 E 946.05 9498 8522.00 8500.00 2288.92 S 1106.52 E 976.93 9631 8622.00 8600.00 2369,50 S 1074,24 E 1009,36 31.64 30.80 30.68 30.89 32.42 9765 8722.00 8700.00 2451.38 S 1038.98 E 1043.33 9899 8822,00 8800.00 2532.41 S 1000,61 E 1077.65 10032 8922.00 8900.00 2610.31 S 959.92 E 1110,79 10163 9022,00 9000.00 2685.57 S 921.33 E 1141.75 10190 9042,17 9020.17 2700.61 S 913.88 E 1147.83 33.97 34.32 33.14 30.97 6.08 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS PRUDHOE BAY DRILLING PBU/12-10A .... 500292058600 NORTH SLOPE COMPUTATION DATE: S~:u;;~RY-SUN DRILLING SERVICES~-'~- ~~ DATE OF SURVEY' 10/27/92 MAR 09 1993 ELECTRONIC SURVEY SYSTEM JOB NUMBER' AK-EI-20084 ~askaOil&SasCons. Commissio~ Anchorage PAGE 1 KELLY BUSHING ELEV. = 22.00 FT. OPERATOR' ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST SECT. 7350 6891.00 6869.00 7500 7006.51 6984,51 7595 7077.88 7055,88 7688 7146.25 7124.25 7782 7216.99 7194,99 40 5 S 49.90 E .00 959.00S 1262.00E 1304.29 40 34 S 31.30 E 7.96 1032.55S 1324.93E 1393.77 42 10 S 19.27 E 8.53 1089.13S 1351.54E 1455.83 42 5 S 10,16 E 6.63 1148.75S 1367.21E 1517.36 41 27 S 3.93 E 4.43 1211.35S 1374.97E 1579.27 7876 7286.90 7264.90 7971 7357.63 7335.63 8062 7426.43 7404,43 8155 7497.18 7475,18 8248 7567,62 7545.62 42 13 S 2.65 W 4.75 1273.85S 1375.64E 1638.87 41 22 S 9.65 W 4.99 1336.63S 1368,90E 1696.43 40 43 S 14.23 W 3,38 1395.20S 1356.53E 1748.24 40 36 S 14.33 W .13 1454,10S 1341,54E 1799.54 40 29 S 14.10 W .21 1512.53S 1326.74E 1850,46 8342 7638,87 7616.87 8434 7709.48 7687.48 8528 7781.00 7759.00 8623 7853.32 7831,32 8718 7925.92 7903,92 40 23 S 14.42 W .24 1571.38S 1311.78E 1901,72 40 20 S 14.00 W .30 1629.56S 1297.05E 1952.42 40 14 S 13.96 W .11 1688.40S 1282,40E 2003.78 40 6 S 14,32 W ,28 1747.61S 1267.48E 2055.40 39 59 S 14,82 W ,37 1806.67S 1252.13E 2106.74 8812 7998.18 7976.18 8906 8069.80 8047.80 8998 8139.94 8117.94 9093 8211.95 8189.95 9187 8284.25 8262.25 39 51 S 15.13 W .25 1865.09S 1236.50E 2157,39 40 26 S 16.15 W .93 1923.27S 1220.21E 2207.61 40 58 S 15,93 W ,60 1981,28S 1203.54E 2257.54 40 5 S 15,08 W 1,11 2040.60S 1187.08E 2308,78 40 9 S 14,54 W ,38 2099,50S 1171,50E 2359.91 9279 8354.11 8332.11 9372 8425.18 8403.18 9465 8496.21 8474.21 9558 8566.97 8544.97 9652 8638,01' 8616,01 40 5 S 17.57 W 2.14 2156.06S 1155.22E 2408.59 40 2 S 20,00 W 1.68 2212.64S 1135.97E 2456.36 40 15 S 21,75 W 1.24 2268,63S 1114.61E 2502.91 40 53 S 21.57 W ,69 2324.96S 1092,24E 2549.48 41 31 S 22,78 W 1.08 2382.57S 1068.75E 2596.91 9747 8708,79 8686.79 9840 8778.29 8756.29 9935 8848.94 8826.94 10030 8920,19 8898.19 10121 8989,81 8967,81 41 55 S 23.83 W .84 2440,53S 1043.77E 2644.21 41 53 S 25.52 W 1.20 2497.20S 1017.74E 2689.96 41 46 S 27,72 W 1.55 2553,71S 989,42E 2734.84 40 32 S 27,34 W 1.33 2608,94S 960,64E 2778.36 40 4 S 27.07 W ,55 2661,45S 933.64E 2819.86 10215 9061.88 9039.88 39 42 S 26.16 W .73 10251 9089.55 9067.55 39 50 S 26,22 W .41 2715,31S 906,66E 2862,63 2735.97S 896.50E 2879.11 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2879.11 FEET AT SOUTH 18 DEG, 8 MIN, EAST AT MD = 10251 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 161.86 DEG. F~ '~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGL PRUDHOE BAY DRILLING PBU/12-10A 500292058600 NORTH SLOPE COMPUTATION DATE: 11/ 3/92 DATE OF SURVEY: 102792 JOB NUMBER: AK-EI-20084 KELLY BUSHING ELEV. = 22,00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7350 6891,00 6869.00 959.00 S 1262.00 E 8350 7644.74 7622.74 1576.22 S 1310.54 E 9350 8408,18 8386,18 2199.22 S 1140,86 E 10251 9089.55 9067,55 2735.97 S 896.50 E 459.00 705.26 246.26 941.82 236.56 1162.07 220.26 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SJ;:::~-RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/12-10A 500292058600 NORTH SLOPE COMPUTATION DATE: 11/ 3/92 DATE OF SURVEY: 102792 JOB NUMBER: AK-EI-20084 KELLY BUSHING ELEV. = 22.00 OPERATOR: ARCO ALASKA ZNC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 7350 6891.00 6869.00 959.00 S 1262,00 E 459.00 7390 6922.00 6900.00 976.60 S 1281.14 E 468.47 9.47 7521 7022,00 7000.00 1044,13 S 1331.53 E 499.42 30.96 7655 7122.00 7100,00 1127.35 S 1362.70 E 533.39 33.97 7789 7222.00 7200.00 1215.78 S 1375.25 E 567.54 34.15 7923 7322,00 7300,00 1305.33 S 1373.19 E 601.86 34.32 8056 7422,00 7400,00 1391,49 S 1357.44 E 634,85 32.98 8188 7522.00 7500.00 1474.73 S 1336.28 E 666,67 31.82 8320 7622.00 7600,00 1557.48 S 1315.36 E 698.14 31.47 8451 7722.00 7700.00 1639.88 S 1294,48 E 729.39 31,25 8582 7822.00 7800.00 1722.04 S 1274.00 E 760,42 31.04 8713 7922,00 7900.00 1803.49 S 1252.97 E 791.10 30.68 8843 8022,00 8000.00 1884,29 S 1231,31 E 821,48 30.37 8974 8122.00 8100,00 1966,29 S 1207.81 E 852.92 31.44 9106 8222.00 8200.00 2048.77 S 1184.88 E 884.56 31.64 9237 8322,00 8300.00 2130.27 S 1163.31 E 915.36 30.80 9368 8422,00 8400,00 2210,13 S 1136.89 E 946.05 30.68 9498 8522,00 8500.00 2288.92 S 1106.52 E 976.93 30.89 9631 8622,00 8600,00 2369.50 S 1074,24 E 1009.36 32.42 9765 8722.00 8700.00 2451.38 S 1038.98 E 1043,33 33,97 9899 8822.00 8800,00 2532.41 S 1000,61 E 1077,65 34.32 10032 8922.00 8900,00 2610.31 S 959,92 E 1110.79 33.14 10163 9022.00 9000.00 2685.57 S 921.33 E 1141,75 30,97 10190 9042,17 9020.17 2700.61 S 913.88 E 1147.83 6.08 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS AOGCC GEOLOGICAL MATERIALS INVENTORY LIST PERMIT ~t ~'~- - ~:~ WELL NAME ~ f.~ , ~ I~ --t1~ COMPLETION DATE It I I ~ ! c~Z.. CO. CONTACT ~.~ che'~' Off [~r iist data as ii' is received.*list received date for 407. if not required ,list as NR ."z'l ~' "t i'l~lq~ d,...e "'~to~' ~/'" ."--.Y t-~' !",,." tests' ~,1 core descr.!ptiofl'N~i~ c,o,,[ed !nte~a!s core analysi,s,,, ~ d~,ditch intcr~als d,!oital data ~~ .... ~,, .~ ...... ~ t4q~ ~ ' 1! n ii Il I I I 11 III I III III ,, i ,,1 , I I III I I II II I · I ~ II III II I I q I I I I I I II I LOG TYPE ' ' RUN INTERVALS SCALE ........ , NO. , (to the nearest foot! linch/lO0'} J iii i ii i i ii i i i iJ i i i i ,~ ............................. i ii i i i i1 i i ti LI I II I LJIIL[ . .......... I II I II II I III II Illll I I I I Ill I I II II III ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-18-92 11-1692 Prod Profile lhm 1, ~" Prod Profile ~m L 5" Tmperature ~ 1, 5" InJ Prot~e l~m 1, ~' Jewelry l~m 1, ~" Jewelry ~,,m 1,~" Prod Profile l~m 1, ~ InJ Profile Run 1, I{" Please sign and return the attached copy ,as receipt of dat~ Sonya Wallace Alaska 0ii & Gas Cons. Commission AT0-1529 Anchorage # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PmI22~ PB WEI2~ FII2~ R&D #BPX # STATE OF ALASKA TEXACO ARCO Alaska, Inc. P.O.Box 100360 Anchorage, ~ 99510 DATE: 11-20-92 ARCO MAGNETIC TAPE(S] WITH LISTINGS DLL/AC/GR R~_m 1 DLL/C-ZDL/GR Run 1 DLL/MLL/AC/GR R~m 1 DII /AC/C /C Run 1 BCS/DTE R"" I Please sign and return the attached copy as receipt of dat~ RECEIVED BY_,>~ ~ Have A Nice Day~ Sonya Wallace ATO-1529 Arias Atlas Atlas Aths Sch APPROVED :~ Tr~ns# 9225~-~-'---- CENTRAL FILES (CH) CHEVRON D&M # BO~ ~ (OH/GC~ # EXXON MARATHON MOBIL # pn~r. rpS PB WELL FILES R&D # BPX # STATE OF ~KA TEXACO RECEIVED NOV 1 9 1992 Alaska Oil & Gas Cons. Commission Anchorage ARCO Ahska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DAT]~ 11-20-92 REFERENCE: ARCO OPEN HOLE FINALS 8$TVD DLL/GR ZDL/CNL/GR ZDL/CNL/GR [Poro] BH Profll~ BHCA/GR Dr~L/GR BHCA/GR Cm,/GR/CCL DPR/GR DPR/GR 7'~P SSTVD PISFL Color Color Color Run 1, 1'&2~ ~/ Run I. 3"&5' ~/ Run 1, 3"&5' ~/ R~ 1. ~ ~ R~ 1. ~ / R~ 1, ~ ~ R~ 1, 5~ ~ R~ 1. 1~ / R~ 1, ~'~ ~ R~ 1, ~'~ ~ R~ 1. 1"~ ~ R~ 1, 2'~ R~ 1.2'~ ~ R~ 1, 2'~ ~' R~ 1, 1"~ ~ R~ 1. 2'~ R~ 1, ~'~ ~/ R~-, ~ Please sign and return the attached copy as receipt of dat~ RECEIVED BY Have A Nice Day~ Sonya Wallace ATO-1529 Arias Arias Aaa Aaa Arias Arias Arias Teleco Teleco 8ch 8ch # CENTRAL FILES # CHEVRON #D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PtHLLIPS # PB WELL ~ R&D # BPX # STATE OF ALASKA # TEXACO RECEIVED 1992 Alaska Oil & Gas Cons. Commission Anchorage 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 September 1, 1992 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re': Prudhoe Bay Unit DS 12-10A ARCO Alaska, Inc. Permit No. 92-89 Sur. Loc. 768'NSL, 733'EWL, Sec. 18, T10N, R15E, UM Btmnhole Loc. 2087'SNL, 254'EWL, Sec. 20, T10N, R15E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. ~hnst~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA L)IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25. OO5 la. Type of work Drill [] Redrill I;'lllb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] 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 ARCO Alaska, Inc. KBE =- 71feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL ~ ~ ? ~3 / x~< 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 20 ^^c 2s.o25) 768' NSL, 733' EWL, SEC. 18, TION, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well number Number 1950' SNL, 300' EWL, SEC. 20, TION, R15E, UM DS 12-10A U-630610 At total depth 9. Approximate spud date Amount 2087' SNL, 254' EWL, SEC. 20, TION, R15E, UM 9/10/92 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(UDandmVD) property line ADL 28335/3191'feet No near well proximty feet 2560 10367'MD/9118'TVD~eet 16. To be completed for deviated wells 17. Anticipated pressure (s~ 20 Mc 25.035 (e)(2)) Kickoff depth ~'~5ofeet Maximum hole angle ,~,~.,~ o Maximum surface 3330Psig At total depth (TVD) ~l~O0'/4390psig 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) 8-1/2" 7" 26# 13crSO/L80 Fox/NSCC 3167' 7200' 6770' 10367' 9178' 485 sx Class "G" RFG IV U 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured lO505feet Plugs (measured) AUG 2:7 1992 true vertical 9565feet Alaska.0il & Gas Cons. C0m~'tssio~ Effective depth: measured 10475feet Junk (measured) ~nch0rage true vertical 9537feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 20" 232 sx AS II 110' 110' S u rface 2642' 13-3/8" 2700 sx Fondu & 2642' 2642' Intermediate 400 sx PF II Production 9662' 9-5/8" 500 sx Class "G" 9662' 8778' Liner 1138' 7" 400 sx Class "G" 9367'-10505' 8507,-9565' Perforation depth: measured 9730'-9756', 9812'-9862', 9884'-9898', 9906'-9922', 9932'-9950' true vertical 8841'-8865', 8917'-8964', 8984'-8997', 9004'-9019', 9029'-9045' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l'~l Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (..~A~ ~?~... (',,' Title Drilling Engineer Supervisor Date's-'--? ? '~''? (.~' ~)- Commission Use Only Permit Number IAPI number IApproval date ISee cover letter 15 o- o ? o o / I g '~/" f4:~ Ifor other requirements Conditions of appr6val Samples required [] Yes .l~'No Mud log r~quired [] Yes ~;~NO Hydrogen sulfide measures [] Yes ~ No Directional survey requ~rea ~ Yes [] No Required working pressure for BOPE []2M; F-13M; ~[5M; F-IIOM; 1-115M; Other: Original Signed By by order of Approved by [~avid Wo Johnston Commissioner [ne commission Date ~'--,/--'~'~' Form 10-401 Rev. 12-1-85 Submit in triplica IOPOSED REDRILL PROGR~ WELL 12-1gA OBJECTIVE: The objective of DS12-10A redrill is water shut-off. A redrill is believed to be the most optimal use of the production slot. The well was shut-in in Oct. '91, and was brought back on in Feb. '92 at about 200BOPD, with watercut of about 90% and 1000GOR. The well will be fracced post-sidetrack. Est. post-frac, production rate is 1000BOPD at 65% water-cut and 1000GOR. Anticipated BHP: 8.1 ppg equivalent. Drilling Fluid: 9.5-9.8 ppg, Workover Fluid: 8.5 ppg. The scope of work is as follows: Plug and abandon the original perforations. Pull the existing 5-1/2" 17# L-80 tubing completion. Mill a section in the 9-5/8" casing strings and lay a cement plug below and across the section. Kick-off and drill a new 8-1/2" hole to a TD of 150' MD below the prognosed BOS and 1500' departure from the current wellbore. Run wireline conveyed open hole logs. Install a 7" 26# 13CR liner and recomplete with 4- 1/2" 13CR tubing. CURRENT STATUS DS12-10 was spudded with Parker #176 on 5/10/81. It was perforated in upper Z4 in FEB82 and initially produced 2000 BOPD. Addition of lower Z4 perfs in DEC85 increased the WC from 3% to 50% without significantly adding to the oil rate. After the well was placed on gas lift in JAN86, the production declined rapidly from 4000 BFPD to 1000 BFPD in February 1988. A PPROF in JUL88 showed the majority of the production from the bottom two sets of perfs and SWBT across the upper perfs. The lower intervals did not show increased gamma ray readings, indicating formation water production. A PITS in October 1988 showed no channel, indicating behind pipe isolation between the perfs at 9950' MD and the OOWC at 9996' MD. DS12-10 was fracced in OCT89. Prior to the frac, sand was placed to 9890' to isolate the high WC lower Z4 intervals and limit potential downward fracture growth. The Sag was perfed and fracced in NOV89. Post-stimulation, the well flowed 7512 BOPD, 35% WC, 624 GOR without AL. Rate soon dropped to 4600 BOPD. Following a FCO, the WC jumped from 50% to 65% and oil production dropped by about 1000 BPD. A PPROF in APR90 showed nearly 25% of production from the lowest perforated interval (2200 bwpd at 100% WC). The flowing temperature log showed what appears to be a channel to the aquifer/Z3 and influx water. A BP was set at 9870' isolating the bottom 3 sets of perforations in OCT90, initially reducing the WC from 83% to 78%, and oil rate by 100 BPD. Oil rates continued to drop while WC increased to over 90%. The well was shut in during late 1991, and was brought back on in February 1992 at about 200 BOPD, with watercuts of about 90% and 1000 GOR. EOR response from WAG injection in 12-31 has not been observed to date. RECEIVED AU G 2 ? 1992 /tlas~a 0il & Gas Cons. Commission Anchorage PROPOSED REDRILL PROGRAM WELL 12-10A DS 12-10A AFE SUMMARY PROCEDURE Procedure Outline' · 2~ 5~ 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. Pre-rig work: Kill well. Lay cement plug across perfs to at least 100' above top perforation. Cut 5-1/2" tubing at +/- 9290' MD. Freeze protect. Set 5-1/2" BPV. MIRU workover rig. Pull 5-1/2" BPV. Circulate diesel from well. Set two-way check valve. ND tree. NU & test BOP's to 5000 psi. PU on 5-1/2" tubing. Pull and lay down tubing. Test 9-5/8" packoff to 3000 psi and replace if necessary. RIH with section mill & cut 60' window in the 9-5/8" casing from 7345"-7405' MD. Set a cement plug from 7145'- 7505' MD. RIH w/steerable system and kickoff through the section. POOH. RIH with 8-1/2" packed assembly and drill to TD (.+. 10,367' MD). Run and cement 7" 13CR/L80 liner in the 8-1/2" hole w/+/- 150' of lap. Clean out liner to PBTD and test to 3000 psi. Displace well to seawater. RIH with 4-1/2" 13CR completion string w/7" packer. Circulate corrosion inhibitor, space out, land completion, and set packer at +/- 9500' MD (to have the tubing tail at least 100' above the Sag). Test down tubing to 4000 psi. Test tubing x casing annulus to 3500 psi. Set two-way check valve. ND BOP's. NU and test 5-1/8" 5M tree to 5000 psi with diesel. Pull two way check valve. Shear RP valve and freeze protect. Set BPV. Release rig. Perforate well (post rig). Anticipated BHP: 8.1 ppg equivalent. Drilling Fluid: 9.5-9.8 ppg, Workover Fluid: 8.5 ppg. RECEIVED AU G ~ 7 1992 Alaska Oil & Gas Guns. oorf~miss~Or~ Anchorage PROPOSED REDRILL PROGRAM WELL 12-10A PRELIMINARY WELL PLAN WELL: DS 12-10A Redrill PBU A,~L[J..o.~. 50-029-20586-00 (on the original 12-10 well) LOCATION: Surface: 768' FSL, 733' FWL, Sec. 18, T10N, R15E Target: 1950' FNL, 300' FWL, Sec. 20, T10N, R15E @ 8900' ssTVD BHL: 2087' FNL, 254' FWL, Sec. 20, T10N, R15E @ 9047' ssTVD ESTIMATED START: 14 September, 1992 ,,OPR. DAYS TO COMPLETE: 17 CONTRACTOR: Doyon Rig #16 DIRECTIONAL; Kickoff at 7350' MD. turn.) (4.0 degree angle build and 58 degree west WELLBORE: Item TVD(BKB) .MD(BKB). Mud Wt. 20" CONDUCTOR 110' 110' N/A 13-3/8" SHOE 2642' 2642' N/A KOP 6891' 7350' 9.3 TOP SAG RIVER 8601' 9643' 9.5 TOP SHUBLIK 8926' 1 0098' 9.5 TOP SADLEROCHIT 8971' 101 61' 9.5 TOTAL DEPTH 911 8' 1 0367' 9.5 LOGGING PROGRAM: 8-1/2" Hole: DIL / GR / BHCS / SP MUD: PROGRAM: The milling/drilling fluid program will consist of a 9.3 - 9.8 ppg XCD polymer / KCI water based mud in the 8-1/2" hole. DEPTH DENSITY PV YP INT 10MIN FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) TYPE 6891' 9.3 10 10 5 7 8 0 5 Water to to to to to to to to to Base AU G 2 7 1992_ Alaska .0it & Gas 0ohs. (;ommisS'~On Anchorage PROPOSED REDRILL PROGRAM WELL 12-10A _MUD WEIGHT CALCU,LATIONS / WELL CONTROL: Mud Wt. (8-1/2" Hole): 9.5 ppg. Est. Pore Press. Sag River: Est. Pore Press. Sadlerochit: 4075 psi/8601' ss TVD. 3700 psi/8800' ss TVD. Overbalance Sag River: Overbalance Top Sadlerochit: 174 psi. 650 psi. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be. capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS: CASING DEPTH 7" 26# 13CR-80 FOX 7200' - 10367' MD BURST COLLAPSE TENSILE 7240 psi 5410 psi 604 klbs CEMENT CALCULATIONS: 7" LINER: Measured Depth: Basis: 7200'MD (Hanger)- 10367'MD (Shoe) 40% open hole excess, 40' shoe joint, 150' liner lap and 200' excess above liner with DP. Total Cement Vol: 560 cuft or 485 sxs of Class G blend @ 1.16 Cu ft/Sk TUBING DETAILS: 4-1/2" 12.6# 13CR-80 Fox (0'- 9600' MD) RECEIVED AU 6 2 7 1992 Alaska 0il & Gas Cons. 6ommis¢On Anchorage PROPOSED REDRILL PRO(~RANI WELL 12'10A DOYON RIG #16 MUD & SOLIDS CONTROL EQUIPMENT w I w m m I m Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Triflow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 H P agitators Abcor 10 HP agitators 40 bbls trip tank Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console RECEIVED AU G 2 7 1992 Alaska 0il & 6as 0ohs. c0mmissio~ Anchorage SUI-,.,"J, CE HOLE DIVERTER SYSTEM -. .... Two lines venting 90 deg. apart in directions that ensure safe down wind venting, and ex- tending to ~ point at least 100' lrom any potential source of ignition. 10' Full Opening Valves -35' or as required Dresser Sleeve ,o 1. All pipe connections 150# ANSI Flanges or welded connections and secured to prevent movemenL 2_ Manual 10' [ull opening valves mechanically ~nnected to ensure that one valve is Jail-safe open at ali limes. 10' Diverter l. Jne 3. All tums are 90 deg. and targeted. 10' Full opening ball valve w/Hydraulic Actuator Cellar 20'" Diverter Spool w/1 O' Side Duller RECEIVED A U G 2) ? 1992 Alaska 0il & 6as Cons. Commission Anchorage MEM 1FJFJ0 BOP STACK CONFIGURATION ATTACHMENT II 13 5/8", 5000 PSI WP TRIPLE RAM STACK WORKO VER RISER ANNULAR PREVENTER 2" KILL LINE 1 I PI PE RAMS I I ! I P l PE RAMS i I MANUAL HYDRAULIC GATE GATE DRILLING SPOOL I BLIND RAMS ! 4" CHOKE LINE HYDRAULIC 'MANUAL GATE RECEIVED / Cons. Co~mission~ Anchoram~,/ IDS 1' 2.,,. 10A,XL..S Alaska D S "f 2... 1 (:;lA Prudhoe Elay 812819.2.. M. Minder' (::as in g Iht Iht [:)es a $iz:e Bottom Top Length I....bs · fA '7 91'78 67'70 ,..3'f 67 2A 0. 0 0 (;l 0 SA 0 0 0 () 0 4.A 0 0 0 0 0 5A 0 0 0 0 0 6A CJ 0 0 0 7A 0 0 0 0 0 8A 0 0 0 0 0 9A 0 0 0 0 0 0A 0 0. 0 0 0 Desc C:Jr.ade 't 3CR80 0 0 0 0 0 0 0 0 [:) e: s "Fhread NS(:::(:: 0 () 0 0 0 0 0 Tension Lbs 0 0 o 0 0 0 0 0 0 0 lB 2..E~ 4.B 5EJ 6B 8B 9D IvJud Wieglnt PPg 9.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 F..iyd C~.r~di er'~t psi/ft O. 510 O. 00(.) 0.000 O.OOQ 0.000 0.00() 0.000 O.00O 0.000 O.OOO Surfaoe psi 4.390 0 0 () () 0 0 0 0 0 M i r"~ i m u m Yield 72..4.0 0 0 () 0 0 0 0 0 0 4.C 6C '70 8C 'f 0C: Tension KJL.bs 82.34-2 0 0 0 0 0 0 0 0 0 Strength 604- 0 0 0 0 0 0 0 TIt) IF: # 11) liV~fO ~ # Bat...PSI 4.67'7 0 0 0 0 0 0 0 0 0 Collapse. Resist. 54.10 () 0 0 () 0 0 Page AI.~ OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend Operation Shutdown Re-enter suspended well Alter casing ~ Repair well ~ Plugging x Time extension ~ Stimulate ~ Change approved program ~ Pull tubing Variance Perforate Other x ~ Plugback for Redrlll 2. Name of Operator ARCO Alaska,/nc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory Stratigraphic Service 4. Location of well at surface 768' NSL, 733' WEL, SEC. 18, TION, R15E, UM At top of productive interval 1114' SNL, 1536' NWL, SEC. 20, TION, R15E, UM At effective depth 1297' SNL, 1689' NWL, SEC. 20, TION, R15E, UM At total depth 1305' SNL, 1696' NWL, SEC. 20, TION, R15E, UM Aus 1 2 1992 Alaska 0il & Gas Cons. C0mmis~ 12. Present well condition summary Total depth: measured true vertical 10505 feet 9565 feet Anchorage Plugs (measured) 6. Datum elevation (DF or KB) KBE = 71' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 12-10 9. Permit number 81-53 10. APl number 50- 029-20586 11. Field/Pool ,~011 Prudhoe Bay Field/Oil Pool Effective depth: measured 10475 feet Junk (measured) true vertical 9537 feet Casing Length Size Cemented Measured depth Structural Conductor 110' 20" 232 sx AS/I 110' Surface 2642'; 13-3/8" 2700 sx Fondu & 2642' Intermediate 400 Sx Permafrost/I Production 9662' 9-5/8" 500 sx C/ass "G" 9662' Liner 1138' 7" 400 sx Class "G" 9367'-10505' Perforation depth: measured 9730'-9756; 9812'-9862', 9884'-9898', 9906'-9922; 9932'-9950' True vertical depth 110' 2642' 8778' 8507'-9565' true vertical 8841'-8865', 8917'-8964', 8984'-8997', 9004'-9019', 9029'-9045' Tubing (size, grade, and measured depth) 5-1/2", N-80, 12.6#, to 9332'; 4-1/2", 12.6#, N-80 tubing tail to 9392' Packers and SSSV (type and measured depth) Baker SAB packer @ 9320'; Camco Bal-O SSSV @ 2179' 13. Attachments Description summary of proposal x .. Detailed operations program BOP sketch 14. Estimated date for commencing operation 9/1/92 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas~ Suspended ~ Service 17. i hereby certif~ylhat the~.j/f°reg°ing is true and correct to the best of my knowledge. Signed ~-/[ ~ Title Drilling Engineer Supervisor Date ' ( .], /]"--- FOR COMMISSION USE ONLY Conditions of approval: N'~t. if~Commission so representative may witness veal CiA°pr°vel No. Plug integrity /~ BOP Test Location clearance ~P~eOturrte2p, Mechanical Integrity Test~ · Approved by order of the Commission Subsequent form required 10- Original Signed By David W. Johnston --~07 Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (2) Log,,, [2 thru 8] ~'[9 thru 13] [ 10 & 13] (4) Casg /--~/?'~'~ [14 thru 22] (5) BOPE [23 thru 28] Company /~ r c~ Lease & Well ~ ~Z)/_ YES 1. Is permit fee attached ............................................... ~.,. 2, Is well to be located in a defined pool .............................. 3. Is wel 1 located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5, I.s sufficient undedicated acreage available in this pool ............. 6, Is well to be deviated 8- is wellbore plat included ................... · 7. Is operator the only affected party .................................. 8, Can permit be approved before 15-day wait ............................ NO e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... I s admi n i st rat i ve approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & ngrnber ................................ 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 ,~OO~ ps ig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS Other /~C [29 thru 31] (7) Contact [32] ( 8 ) Ad d 1 geology' DWJ~ [_AG en9ineerin9: BEW ~ JDH~_~Z 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressur.e zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE remarks' rev 08/18/92 jo/6.011 O ~0 c-~rn rn z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIx. No special 'effort has been made to chronologically organize this category of information. 0 ALASKA INC D.S. 12 - 10A ~~~'? PRUDHOE BAY MICltOFILMED Run 1' 28 - October - 1992 DLL/MLL/AC/GR ?332 0266 RECEIVED NOV 19 1992 Alaska Oil & Gas Cons. Commission Anchorage Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: D.S. 12 - 10A 500292058601 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 04-NOV-92 RUN1 RUN2 RUN3 5737.00 J. DAHL L. WATKINS K. HUDSON E. POTTER 20 i0N 15E 768 733 71.00 70.00 40.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 7345.0 DLL/MLL/AC/GR CIRCULATION STOPPED: 15:00 27-0CT-92. TD NOT LOGGED DUE TO HOLE PROBLEMS. TOOL STICKING IN MANY PLACES. MICROLATEROLOG AND CALIPER CLOSED AFTER 9960' ON MAIN PASS. DLL/GR LOGGED TO CASING POINT. AC TOOL CYCLE SKIPPING ABOVE SADLEROCHIT DUE TO HOLE CONDITIONS. $ FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BHC DLL $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 START DEPTH STOP DEPTH 7332.0 10223.0 9903.0 10242.0 7332.0 10266.0 GR (MEASURED DEPTH) BASELINE DEPTH DT 7332.0 7332.0 7387.0 7402.5 7416.0 7446.0 7507.0 7507.5 7522.5 7526.5 7540.5 7580.0 7602.0 7630.0 7653.5 7665.5 7674.5 7678.0 7682.5 7683.0 7693.0 7693.5 7713.5 7735.5 7736.0 7777.0 7920.0 7940.0 7940.5 8108.0 8188.0 8246.5 8255.5 8288.5 8290.5 8335.0 8400.0 8454.5 8506.0 8524.5 8531.0 8546.5 all runs merged; EQUIVALENT UNSHIFTED DEPTH LL3 LLD MLL 7332.0 7332.0 7332.0 7387.5 7403.0 7403.0 7416.5 7446.5 7507.5 7508.0 7527.0 7540.0 7653.0 7674.5 7683.5 7693.0 7735.5 7940.5 8247.0 8288.5 8400.0 8531.0 8547.0 7523.0 7540.5 7580.0 7602.0 7629.5 7653.0 7665.5 7678.5 7683.0 7693.0 7713.5 7736.0 7777.0 7920.0 7940.0 8108.0 8188.5 8247.0 8256.0 8290.5 8334.5 8400.0 8454.5 8506.0 8524.5 8531.0 no case 8549. 8614. 8702. 8706. 8728. 8754. 8785. 8806. 8853. 8876. 8880. 8892. 8901. 8904. 8918. 8918. 8939. 8994. 8999. 9012. 9021. 9022. 9027. 9030. 9048. 9050. 9052. 9054. 9066. 9085. 9090. 9091. 9093. 9099. 9110. 9114. 9125. 9140. 9140. 9154. 9175. 9179. 9192. 9207. 9257. 9288. 9306. 9337. 9349. 9362. 9373. 9403. 9410. 9467. 9488. 9488. 9519. 9522. 9542. 9585. 8549.5 8614.0 8702.0 8728.0 8785.0 8901.5 8919.0 9022.5 9028.5 9050.5 9054.5 9090.0 9094.5 9110.0 9115.0 9125.0 9140.5 9193.0 9288.5 9306.0 9338.0 9349.5 9373.5 9404.0 9468.0 9488.5 9519.0 8549.5 8614.0 8702.0 8706.5 8728.0 8754.0 8785.0 8806.5 8853.5 8877.0 8881.0 8893.0 8905.0 8918.5 8939.5 8994.5 8999.5 9012.5 9022.0 9031.0 9048.5 9052.5 9066.5 9085.0 9091.5 9099.5 9115.0 9125.0 9141.0 9154.5 9175.5 9179.5 9193.0 9207.5 9258.0 9288.5 9306.0 9338.0 9349.5 9362.0 9373.5 9411.0 9467.5 9489.0 9522.0 9542.5 9585.0 9642.5 9650.0 9650.5 9699.5 9814.5 9829.0 9829.5 9838.0 9839.0 9928.5 9960.0 9960.5 9964.5 9968.0 9978.5 9979.0 9981.5 9993.5 10012.5 10028.0 10034.0 10034.5 10039.5 10040.0 10054.5 10055.0 10057.5 10061.0 10067.0 10068.0 10076.0 10076.5 10083.0 10092.0 10120.5 10121.5 10122.0 10130.0 10130.5 10138.0 10145.0 10168.5 10169.0 10177.5 10180.0 10181.0 10181.5 10192.0 10194.0 10201.0 10260.0 $ MERGED DATA SOURCE PBU TOOL CODE GR GR BCS BCS DLL 9650.5 9700.0 9830.0 9838.5 9642.5 9650.0 9700.0 9815.5 9830.5 9839.5 9928.5 9959.5 9960.5 9960.5 9964.5 9964.5 9967.5 9979.0 9979.5 9981.5 9993.5 9993.5 10012.5 10028.0 10033.5 10034.0 10039.0 10039.5 10054.5 10054.5 10054.5 10057.0 10060.5 10067.0 10067.5 10067.5 10075.5 10076.0 10083.5 10092.0 10121.0 10121.0 10121.5 10121.5 10130.0 10130.5 10138.5 10145.5 10168.5 10168.5 10177.0 10180.5 10180.5 10180.5 10182.0 10192.0 10194.5 10201.5 10260.0 10260.0 10260.0 10260.0 RUN NO. 1 1 1 1 1 PASS NO. 5 3 5 3 5 MERGE TOP 7332.0 10211.0 9903.0 10232.0 7332.0 MERGE BASE 10211.0 10223.0 10232.0 10242.0 10202.0 DLL $ REMARKS: CN WN FN COUN STAT 1 3 10202.0 10266.0 EDITED OPEN HOLE MAIN PASS. TENS, TEND, & MTEM WERE SHIFTED WITH LL3. SP WAS SHIFTED WITH LLD. CALl WAS SHIFTED WITH MLL. THE BOTTOM PORTION OF THE REPEAT PASS WAS SPLICED ONTO THE MAIN PASS FOR COMPLETE DATA COVERAGE. NOTE: MLL (& CALl) SPLICE DEPTH = 10255'. $ : ARCO ALASKA INCORPORATED : D.S. 12 - 10A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 TEND BCS 68 1 LB 4 4 TENS BCS 68 1 LB 4 5 LL3 DLL 68 1 OHMM 4 6 LLD DLL 68 1 OHMM 4 7 MLL DLL 68 1 OHMM 4 8 SP DLL 68 1 MV 4 9 CALl DLL 68 1 IN 4 10 MTEM DLL 68 1 DEGF 4 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 256 Tape File Start Depth = 10269.000000 Tape File End Depth = 7332.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 64626 datums Tape Subfile: 2 497 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 7301.0 7332.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CN WN FN COUN STAT CASED HOLE PORTION of MAIN PASS. $ : ARCO ALASKA INCORPORATED : D.S. 12 - 10A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 4 2 MTEM GR 68 1 DEGF 4 3 TEND GR 68 1 LB 4 4 TENS GR 68 1 LB 4 4 21 990 60 6 4 45 987 88 5 4 10 579 41 1 4 10 579 41 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: Tape File Start Depth = 7332.000000 Tape File End Depth = 7268.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 3 Minimum record length: Maximum record length: 646 datums 28 records... 62 bytes 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 5 0.2500 VENDOR TOOL CODE START DEPTH GR 7301.0 AC 9903.0 DLL 7332.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 10214.0 10234.0 10257.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP PCM MIS DLL GR MIS AC KNJT KNJT CAL MLL $ CABLEHEAD TENSION TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG GAMMA RAY MASS ISOLATION SUB BHC-ACOUSTILOG KNUCKLE JOINT KNUCKLE JOINT i-ARM CALIPER MI CROLATEROLOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): 28-0CT-92 FSYS REV. J001 VER. 1.0 1500 27-OCT-92 506 28-OCT-92 10305.0 10294.0 7332.0 10266.0 1800.0 TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229MA/1229EA 1309XA 3967XA 1603MA/1609EB 3921XA 3921XA 1233XA 1233XA 8.500 7345.0 7332.0 KCL POLYMER 10.10 59.0 9.0 5.6 MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 12 - 10A : PRUDHOE BAY : NORTH SLOPE : ALASKA 182.0 0.114 68.0 0.043 182.0 0.102 68.0 0.000 0.0 0.206 68.0 0.000 0.0 0.00 0.000 2.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 ACQ AC 68 1 4 4 TlR1 AC 68 1 US 4 5 TlR2 AC 68 1 US 4 6 T2R1 AC 68 1 US 4 7 T2R2 AC 68 1 US 4 8 CHT AC 68 1 LB 4 9 TTEN AC 68 1 LB 4 10 RD DLL 68 1 OHMM 4 11 RS DLL 68 1 OHMM 4 12 RMLL DLL 68 1 OHMM 4 13 SP DLL 68 1 MV 4 14 CAL DLL 68 1 IN 4 15 ED DLL 68 1 MV 4 16 ID DLL 68 1 A 4 17 SPD DLL 68 1 F/MN 4 18 TEMP DLL 68 1 DEGF 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 39 859 45 0 4 40 514 81 0 4 62 614 26 5 4 23 415 80 5 4 44 339 70 5 4 30 739 95 0 4 30 739 95 0 4 11 639 82 1 4 84 503 82 1 72 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 921 Tape File Start Depth = 10260.000000 Tape File End Depth = 7268.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 292038 datums Tape Subfile: 4 1002 records... Minimum record length: Maximum record length: 62 bytes 994 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE S[/MMARY 1 1 3 0.2500 VENDOR TOOL CODE START DEPTH GR 10076.0 AC 10076.0 DLL 10076.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 10223.0 10242.0 10266.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP PCM MIS DLL GR MIS AC KNJT KNJT CAL MLL $ CABLEHEAD TENSION TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG GAMMA RAY MASS ISOLATION SUB BHC-ACOUSTILOG KNUCKLE JOINT KNUCKLE JOINT i-ARM CALIPER MICROLATEROLOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 28-OCT-92 FSYS REV. J001 VER. 1.0 1500 27-OCT-92 2341 27-OCT-92 10305.0 10294.0 7332.0 10266.0 1800.0 TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229MA/1229EA 1309XA 3967XA 1603MA/1609EB 3921XA 3921XA 1233XA 1233XA 8.500 7345.0 7332.0 KCL POLYMER 10.10 59.0 9,0 5.6 182.0 MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 12 - 10A : PRUDHOE BAY : NORTH SLOPE : ALASKA 0.114 68.0 0.043 182.0 0.102 68.0 0.000 0.0 0.206 68.0 0.000 0.0 0.00 0.000 2.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units 1 GR AC 68 1 GAPI 2 AC AC 68 1 US/F 3 ACQ AC 68 1 4 TlR1 AC 68 1 US 5 TlR2 AC 68 1 US 6 T2R1 AC 68 1 US 7 T2R2 AC 68 1 US 8 CHT AC 68 1 LB 9 TTEN AC 68 1 LB 10 RD DLL 68 1 OHMM 11 RS DLL 68 1 OHMM 12 RMLL DLL 68 1 OHMM 13 SP DLL 68 1 MV 14 CAL DLL 68 1 IN 15 ED DLL 68 1 MV 16 ID DLL 68 1 A 17 SPD DLL 68 1 F/MN 18 TEMP DLL 68 1 DEGF API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 06 969 49 6 4 4 48 852 89 1 4 4 81 285 47 0 4 4 81 285 47 0 4 4 81 285 47 0 4 4 81 285 47 0 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 39 859 45 0 4 4 40 514 81 0 4 4 62 614 26 5 4 4 23 415 80 5 4 4 44 339 70 5 4 4 30 739 95 0 4 4 30 739 95 0 4 4 11 639 82 1 4 4 84 503 82 1 72 * DATA RECORD (TYPE# 0) Total Data Records: 62 994 BYTES * Tape File Start Depth = 10269.000000 Tape File End Depth = 10069.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 15866 datums Tape Subfile: 5 141 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 6 is type: LIS 92/11/ 3 01 **** REEL TRAILER **** 92/11/ 5 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 5 NOV 92 10:14a Elapsed execution time = 1 minute , 8.7 seconds. SYSTEM RETURN CODE = 0