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178-092
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NGI-14 PRUDHOE BAY UNIT NGI-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/20/2022 NGI-14 50-029-20348-00-00 178-092-0 G SPT 7255 1780920 1814 3389 3388 3388 3384 19 19 19 19 4YRTST P Adam Earl 6/20/2022 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT NGI-14 Inspection Date: Tubing OA Packer Depth 230 2208 2200 2194IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220622093546 BBL Pumped:2.2 BBL Returned:2.2 Wednesday, July 20, 2022 Page 1 of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y Samantha Carlisle at 9:22 am, Dec 29, 2021 'LJLWDOO\VLJQHGE\%R<RUN '1 FQ %R<RUNF 86R +,OFRUS $ODVND//&RX $ODVND1RUWK 6ORSHHPDLO E\RUN#KLOFRUSFRP 'DWH %R<RUN '65 0*5'(&6)' JLC 1/4/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.01.04 14:50:58 -09'00' RBDMS HEW 1/5/2022 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůEĂŵĞ͗E'/Ͳϭϰ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϬϯϰϴͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗'ĂƐ/ŶũĞĐƚŽƌ >ĞŐ͗ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗:ĂŶ ϭϴƚŚ͕ϮϬϮϮ ZŝŐ͗Eͬ ZĞŐ͘ƉƉƌŽǀĂů ZĞƋ͛Ě͍ϭϬͲϰϬϯ ĂƚĞ ZĞŐ͘ƉƉƌŽǀĂů ZĞĐĞŝǀĞĚ͗ ZĞŐƵůĂƚŽƌLJŽŶƚĂĐƚ͗ĂƌƌŝĞ :ĂŶŽǁƐŬŝ WĞƌŵŝƚƚŽ ƌŝůůEƵŵďĞƌ͗ϭϳϴͲϬϵϮ &ŝƌƐƚĂůů ŶŐŝŶĞĞƌ͗ĂǀĞũŽƌŬ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϰϲϳϮ Ğůů͗ϵϬϳͲϰϰϬͲϬϯϯϭ ^ĞĐŽŶĚĂůů ŶŐŝŶĞĞƌ͗ZLJĂŶdŚŽŵƉƐŽŶ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϱϮϴϬ Ğůů͗ϵϬϳͲϯϬϭͲϭϮϰϬ 'ĂƐ/ŶũĞĐƚŝŽŶZĂƚĞ͗ ΕϮϮϴ͕ϬϬϬ DƐĐĨͬĂLJ /ŶũĞĐƚŝŽŶWƌĞƐƐƵƌĞ͗ϯ͕ϰϰϴ ƉƐŝ ZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞ; ƐƚŝŵĂƚĞͿ͗ϯϮϱϬ ƉƐŝ WƌŽŐƌĂŵKďũĞĐƚŝǀĞ;ƐͿ͗ E'/Ͳϭϰ ŝƐĂŐĂƐ ĐĂƉ ŝŶũĞĐƚŝŽŶǁĞůůƚŚĂƚŚĂƐĚĞŵŽŶƐƚƌĂƚĞĚĂĚĞĐƌĞĂƐĞŝŶŝŶũĞĐƚŝǀŝƚLJ͘dŚĞǁĞůůŚĂƐŶŽƚďĞĞŶǁĂƚĞƌ ǁĂƐŚĞĚƐŝŶĐĞ ϮϬϭϰ͘tĂƚĞƌǁĂƐŚĞƐĂƌĞĚĞƐŝŐŶĞĚƚŽĚŝƐƐŽůǀĞƐĂůƚƐĂŶĚĂƐƉŚĂůƚĞŶĞƐŝŶƚŚĞƚƵďŝŶŐĂŶĚĨŽƌŵĂƚŝŽŶ͘ dŚĞŽďũĞĐƚŝǀĞŝƐƚŽƉĞƌĨŽƌŵĂƚƵďŝŶŐǁĂƚĞƌǁĂƐŚƚŽŝŶĐƌĞĂƐĞŝŶũĞĐƚŝǀŝƚLJĂŶĚƉĞƌĨŽƌŵĂŐĞŶĞƌĂůŵĂŝŶƚĞŶĂŶĐĞŽŶ 'ĂƐ/ŶũĞĐƚŝŽŶtĞůůƐ͘ WƌŽƉŽƐĞĚWƌŽŐƌĂŵ͗ WƵŵƉĚŝĞƐĞůĨŽůůŽǁĞĚďLJ&ƌĞƐŚtĂƚĞƌĂŶĚ^ƵƌĨĂĐƚĂŶƚĂƐƉĞƌĂƚƚĂĐŚĞĚƉƵŵƉŝŶŐ ƚĞŵƉůĂƚĞ͘ tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ • • of MEMORANDUM StateAlaska Alaska Oil and Gas Conservation Commission TO: Jim ReggDATE: Tuesday,June 05,2018 P.I.Supervisor \-46240) q(3/( e SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. NGI-14 FROM: Brian Bixby PRUDHOE BAY UNIT NGI-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry OSP-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-14 API Well Number 50-029-20348-00-00 Inspector Name: Brian Bixby Permit Number: 178-092-0 Inspection Date: 6/3/2018 ,/ Insp Num: mitBDB180603145258 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-14 Type Inj G 'TVD 7255 Tubing 3313 ' 3319 ' 3335 3334 3329- 3328 PTD 1780920 -Type Test SPT Test psi 1814 - IA 11 2500 • 2528 - 2553 2561 - 2565 - BBL Pumped: 4.5 - BBL Returned: 2.3 ' OA 9 • 9 - 10 • 11 11- 11 Interval 4YRTST 1-P/F P Notes: jU 2 L1)14 Tuesday,June 05,2018 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon Repair Well L Plug Perforations Ll Perforate L Other Ld Water Wash Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver Ei Time Extension❑ Change Approved Program ❑ Operat. Shutdown[] Stimulate - Other ❑ Re-enter Suspended Well❑ 2 Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑ Stratigraphic❑ Exploratory ❑ Service ❑ 178-092-0 3 Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-20348-00-00 7 Property Designation (Lease Number): 8 Well Name and Number: ADL0028302 PBU NGI-14 9 Logs (List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 11 Present Well Condition Summary: E C E.- Total Depth measured 9515 feet Plugs measured None feet truevertical 8515.1 feet Junk measured None feet AUG 0 7 2014 Effective Depth measured 9510 feet Packer measured See Attachment feet true vertical 8510.59 feet true vertical See Attachment feet AOGCC Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H-40 29-109 29-109 1530 520 Surface 2840 13-3/8" 72# N-80 28-2868 28-2867.68 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1374 7" 29# N-80 8136-9510 7298.35 - 8510.59 8160 7020 Perforation depth Measured depth See Attachment feet r -.,r � True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4-1/2" Carrico A-1 Injection SSV 2199 2198.9 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8988'-9404' Treatment descriptions including volumes used and final pressure: 600 BBLS FW/F-103 SURFACTANT, 290 BBLS 50/50 DIESEL/XYLENE 13, Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 184781 0 0 3348 Subsequent to operation: 0 222098 0 0 3413 14 Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory{❑ Development ❑ Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil L Gas 0 WDSP GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑✓ SUSP ❑ SPLUC[] 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 314-213 Contact Nita Summerhays Email Nita. Summerhayst2D_bp.com Printed Name Nita Summerhays Title Petrotechnical Data Engineer Signat Phone 564-4035 Date 8/7/2014 UL r RRCMS AUG 12, 11 5 t+1 Iq Form 10-404 Revised 10/2012 l Submit Original Only WE Daily Report of Well Operations ADL0028302 1 n/u=z=u/33/yu ulesel/JCylene I reatment. vumpea 1 u DDI bu/4u spear, ltiu DDIs bu/5u Diesel/Xylene down Tbg. Flushed w/ 602 bbls Fresh water w/ 2% F-103 Surfactant. DSO notified of well status and tree valve positions as follows: SV,WV, SSV partially closed 7/15/2014 well on vac. IA and OA open to gauges. FWHP= 0/12/87 FLUIDS PUMPED BBLS 20 60/40 METH 290 50/50 DIESELAYLENE 600 FW/F-103 SURFACTANT 910 TOTAL AB ABANDONED MIR Perforation Attachment APF ADD PERF MIS MECHANICAL ISOLATED BPP ADL0028302 MILK MECHANICAL LEAK BPS SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base NGI-14 12/13/2010 APF 8050 8054 7224.28 7227.71 NGI-14 1/31/1980 PER 8988 9008 8044.39 8062.21 NGI-14 5/23/1987 APF 9008 9016 8062.21 8069.34 NGI-14 1/31/1980 PER 9016 9036 8069.34 8087.16 NGI-14 5/23/1987 APF 9036 9044 8087.16 8094.28 NGI-14 1/31/1980 PER 9044 9064 8094.28 8112.1 NGI-14 5/23/1987 APF 9064 9080 8112.1 8126.36 NGI-14 1/31/1980 PER 9080 9100 8126.36 8144.18 NGI-14 5/23/1987 APF 9100 9112 8144.18 8154.87 NGI-14 1/31/1980 PER 9112 9142 8154.87 8181.57 NGI-14 5/23/1987 APF 9142 9158 8181.57 8195.79 NGI-14 1/31/1980 PER 9158 9188 8195.79 8222.44 NGI-14 5/23/1987 APF 9188 9203 8222.44 8235.74 NGI-14 1/31/1980 PER 9203 9233 8235.74 8262.33 NGI-14 5/23/1987 APF 9233 9250 8262.33 8277.38 NGI-14 1/31/1980 PER 9250 9280 8277.38 8303.91 NGI-14 1/31/1980 PER 9298 9318 8319.81 8337.53 NGI-14 1/31/1980 PER 9354 9404 8369.73 8414.91 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MILK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Casing / Tubing Attachment ADL0028302 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 29 - 109 29 - 109 1530 520 INTERMEDIAT 2484 9-5/8" 47# L-80 25 - 2509 25 - 2508.79 6870 4760 INTERMEDIAT 5944 9-5/8" 47# L-80 2493 - 8437 2492.79 - 7558.96 6870 4760 LINER 1374 7" 29# N-80 8136 - 9510 7298.35 - 8510.59 8160 7020 SURFACE 2840 13-3/8" 72# N-80 28 - 2868 28 - 2867.68 4930 2670 TUBING 7757 7-5/8" 29.7# L-80 23 - 7780 23 - 6992.79 6890 4790 TUBING 211 7" 26# L-80 7780 - 7991 6992.79 - 7173.64 7240 5410 TUBING 76 4-1/2" 12.6# L-80 8096 - 8172 7263.86 - 7329.46 8430 7500 Packers and SSV's Attachment ADL0028302 SW Name Type MD TVD Depscription NGI-14 SSSV 2199 2150.9 4-1/2" Camco A-1 Injection SSV NGI-14 PACKER 7867 7019.35 7" Baker S-3 Packer NGI-14 PACKER 8096 7215.86 7" Baker FB -1 Packer TTS = CNV W,443ltfAD = MCEVOY ACTUATOR = BAKER C KB. ELEV = 48' BF. ELEV = KOP = 3400' 20' CONDUCTOR 110' Max Angle = _41" @ 7300' 94#, Fido, Daturn MD = 9884' D = 19.1274" Datum TVD = 8800' SS 9-5/8" CSG, 47#, S00-95 XO TO L-80 BTC 2306- 9-5/8' CSG, 47#, L-80 W D 563, D = 8.68' 2505' 9-5/8" BOVV9d CSG PATCH, D = 9.85"2505' - 2509' 13-3/8" CSG, 72#, N-80 BUTT, D = 12.34r 2709' 7-5/8" TBG, 2911, L-80 VAM TOP HC Fr. 7778' .0459 bpf, D = 6.875" Minimum ID = 3.725" @ 8160' 4-1/2" OTIS XN NIPPLE r TBG, 26#, L-80 VAM TOP HC, 1—i 7991' .0383 bpf, D = 6.276" TOP OF 7" LNR H 8136' 14-1/2- TBG -PC, 12.611, L-80,.0152 bpf, ID = 3.958" 1—� 8172' 9-5/8" CSG, 47#, L-80 BTC, D = 8.681" (-� 8437 - 7" LW 29#, N-80 BTC, .0371 bpf, D = 6.184" 951T NG I-14 SAFETY NOTES: ••* WELL REQUIRES A SSSV ••• PERFORATION SLA"RY COh&fNTS REF LOG: BRCS 05/31/79 r CAMCO DB -6 NP. D = 6.00" ANGLE AT TOP PERF: 27* @ 8988' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 3-3/8" 4 8988-9280 O '80 &'87 DRLG DRAFT CORRECTIONS 3-3/8" 4 9298-9318 O 01/31/80 02/11/11 3-3/8" 4 9354- 9404 O 01/31/80 7" LW 29#, N-80 BTC, .0371 bpf, D = 6.184" 951T NG I-14 SAFETY NOTES: ••* WELL REQUIRES A SSSV ••• REV BY COh&fNTS 2199' r CAMCO DB -6 NP. D = 6.00" P`KR 141 INITIAL COMPLETION 2327- 9-5/8" FOC WWS 1 RWO 2459' 9-5/8 D141 RWO 2463' 95/8' HE5 DRLG DRAFT CORRECTIONS 01/11/11 2484' 9-5/8" BKR ISO -ZONE CSG W,R D = 8.75" 7778' -17-5/8" X 7" XO, D = 6276" 7836' 7" HES "R NP, D = 5.963" 7867- —j 9-5/8" X 7" BKR S-3 PSA PKR, D = 6.00" 7901' 7973' 7" HES "RNT NIP, D= 5.n" 7991' r VVLEG, D = 6.276' 9-5/8' X r BKR FB -1 PKR D = 6.00" 8111' 7-5/8" MILLOUT EXTENSKK D 8116' 7-5/8"X4-1/2" XO, D = 4.892" 8136' 9-5/8" X 7" TIEBACK SLV w / LNR HGR, D = ? 8160' 14-1/2" OTIS XN NIP, D = 3.725" 8171' 4-1/7 BAKER BULLNOSE SHEAROUT SUB 8172' 4-1/r TUBING TAIL, D = 3.958' B.MD TT NOT LOGGED DATE REV BY COh&fNTS DATE_ REV_ BY COMAB4TS 06/07/79 P`KR 141 INITIAL COMPLETION 05/26/13 LAC/ PJC lA (ENBJTED 12/"06/88 WWS 1 RWO 01/05111 D141 RWO 01/09/11 ? / PJC DRLG DRAFT CORRECTIONS 01/11/11 HBIPJC FINAL DRLG CORRECTIONS 02/11/11 MB/JL4) JADDEDSSSV SAFETY NOTE PRUDHOE BAY UNIT WELL: NGE 14 PERMIT No: 1780920 API No: 50-029-20348-00 SEC. 1, T11N, R14F-606' FSL & 816' FVVL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission c DATE: Thursday, July 24, 2014 TO: Jim Regg �e , I!� �q SUBJECT: Mechanical Integrity Tests P.I. Supervisor ' l `lI� f BP EXPLORATION (ALASKA) INC NGI-14 FROM: Chuck Scheve PRUDHOE BAY UNIT NGI-14 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-l4 API Well Number 50-029-20348-00-00 Inspector Name: Chuck Scheve Permit Number: 178-092-0 Inspection Date: 6/26/2014 Insp Num: mitCS140627164126 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-14 Type InI G ' TVD 7255 IA PTD 1780920 Type Test SPT Test psi 1814 OA 264 98 2050 99 2075 111 2098 120 -- Intervall4YRTST P/F P Tubing 3250 3250 3250 3250 Notes: Pre test pressures observed for 30 minutes and found stable. Pressures were observed post test and bleed off and were stable verifying thermal expansion during test. , SCANNED OCT 3 0 2014 Thursday, July 24, 2014 Page I of 1 • OF 7. 77,41, \ 77, 0 THE STATE ' \ rN7 Rr` �yrs n�,y ic^i 7i c� .rs r^C t /J tr � _, 333 West Sevenlh Avenue \'LRn.� R SEAN PARNELL Goo �,_ _ Anchorage, AlasKa 99501 3572 7.5 Main: 907.279 1433 SC0860 JUL 2 2 Wk Fr.X. 9c7. 7.;42 Javier Farinez GPB GDE Lead PE BP Exploration (Alaska), Inc. 'I P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU NGI-14 Sundry Number: 314-213 Dear Mr. Farinez: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P7?„5/„, Cathy P. F•erster Chair DATED this J(/' y of April, 2014. Encl. RECEIVED VSD STATE OF ALASKA APR 0 3 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. _Water Wash 0 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 178-092-0 • 3.Address: Stratigraphic ❑ Service Q • 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20348-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU NGI-14 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ti ADL0028302 • PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9515 • 8515 6 9510 8511 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 29-109 29-109 Surface 2840 13-3/8"72#N-80 28-2868 28-2867.68 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1374 7"29#N-80 8136-9510 7298.35-8510.59 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths 4-1/2"Camco A-1 Injection SSV 2199'.2198.g 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program ❑] BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑, • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ 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 Javier Farinez Email Javier.Farinez@BP.Com Printed Name .ier Farinez Title GPB GDE Lead PE Signature / I Phone 564-5043 Date 'L!j ti Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3`Lk— 2—k% Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS MAY 1 0 2014 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 / 0 4 APPROVED BY Approved by: r'/ 6*-1711-1--- COMMISSIONER THE COMMISSION Date: _.76 /7 Form 10-403 Revised 10/2012 c i i v id for 12 months from the date of approval. Submit Form anfd Attachments in Duplicate • -0 O O O O O O p p • a0aoaoaoaocoao = J J Z Z J J J a) Q p 0 0 0 0 O_ O O N r- r- O CO r- 0 p T N- N 0 N U C') N- 7CD M [t O) Ch • 0 ao 00 '� 0) N 00 NI- 03 CD CD '00-ci- N- CO 00 N - u) = - NO) 0)-v- 00 ' M O) m 0) 0 L r CD N- O) N 0 0 0 00 — O) C) Q • N 0- 00 N d� CO N 0. O 01 H 0) 0 0 0 0) 0) 00 0)) C) CD N N N 0 N CD N 0- N E O C C'�) cu 07 O) N- 0 0 O N co co p 0 M N- CO O) 00 N- 0 Nr 0 CO 0) N- — O O ' N 00 O N N- N. 00 VJO _C Q Q N H• O 0 OM) M co co co CO cr U 2 N N N oo N N N 0 O apo 000 p a0 O co 000 CD 00 J J a0 Z 0D J • 4t Z 11 ft 8 00 00 N 60 N N r M rs In T- O) O '- N • _c O O co Tr N _ 0 00 O) co C70 N- N N 0 -- N N N Lu O O 0 . N• U W W U U p c c L Z Z Z Z W W W m E OUZZJf/) HHH Perforation Attachment ADL0028302 Well Date Perf Code MD Top MD Base TVD Top TVD Base NGI-14 12/13/10 APF 8050 8054 7224 7228 NGI-14 1/31/80 PER 8988 9008 8044 8062 NGI-14 5/23/87 APF 9008 9016 8062 - 8069 NGI-14 1/31/80 PER _ 9016 9036 8069 8087 NGI-14 5/23/87 APF 9036 _ 9044 8087 8094 NGI-14 1/31/80 PER 9044 9064 8094 8112 NGI-14 5/23/87 APF 9064 _ 9080 8112 8126 NGI-14 1/31/80 PER 9080 9100 8126 8144 NGI-14 5/23/87 APF 9100 9112 8144 8155 NGI-14 1/31/80 PER 1 9112 9142 8155 8182 NGI-14 5/23/87 APF 9142 9158 8182 8196 NGI-14 1/31/80 PER 9158 9188 8196 8222 NGI-14 5/23/87 APF 9188 _ 9203 8222 8236 NGI-14 1/31/80 PER 9203 9233 8236 8262 NGI-14 5/23/87 APF 9233 _ 9250 8262 8277 NGI-14 1/31/80 PER 9250 9280 8277 8304 NGI-14 1/31/80 PER 9298 _ 9318 8320 8338 NGI-14 1/31/80 PER 9354 9404 8370 8415 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028302 Well Facility Type MD Top Description TVD Top NGI-14 SSSV 2199 4-1/2"Camco A-1 Injection SSV 2199 NGI-14 PACKER 7867 7" Baker S-3 Packer 7067 NGI-14 PACKER 8096 7" Baker FB-1 Packer 7264 • TREE= CNV MEILHEAD= ACEVOBAKERC N G I-14 SAFETY NOTES:••• WELL REQUIRES A SSSV••• KB.BEV= 48' 1 ;: I ��— H 7"CA MCO DB-6 NP,D=6.00" KOP= 3400' 20'CONDUCTOR H 110' i'� , �+, 2199' Max Angle= 41"@ 730(Y 94#,1_1-40, Datum MD= 9884' `rF 'e 2327' H9-5/8"FOC �ID=19.1274" �_ Datum ND= 8800'SS ?:.�\ 2459' —19-5/8"FOC 9-5/8"CSG,47#,S00-95 XO TO L-80 BTC H 2306' ACEMENTER ITC:1 "(+,�\ 9-5/8"CSG,47#,L-80 HY 0 563,0=8.68" —1 2505' }/ 2463' —19-5/8"FES ✓I 2484' H9-5/8"BKR ISO-ZONE CSG PKR D=8.75" 9-5/8"BOVVRN CSG PATCH,D=9.85" —1 2505'-2509' 1 13-3/8"CSG,72#,N-80 BUTT,ID=12.347" - j 2709' / / / 7778' —17-5/8"X 7"XO,D=6.276" 7-5/8"TBG,29#,L-80 VAM TOP HC PC, H 7778' // 7836' —7"HES"RT NP,D=5.963" 1 .0459 bpf,D=6-875" 1 1 Minimum ID = 3.725" @ 8160' 4-1/2" OT IS XN NIPPLE z —_ 786T —19-5/8"x 7"BKR S-3 PERM FKR D=6.00" I 111 7901' —17"HES"IC NP,D=5.963" II I 7973' —{7"HES"RN"NP,D=5.77" 7"TBG,26#,L-80 VAM TOP HC, —1 7991' j---" 1 7991' —{7"WLEG,ID=6.276" .0383 bpf,ID=6.276" g zr— 8096' —19-5/8"X 7"BKR FB-1 PKR D=6.00" 8111' —17-5/8"M LOUT EXTENSION,ID=6.687" l 8116' —7-5/8"X 4-1/2"XO,ID=4.892" TOP OF 7"UP 8136' L L 8136' —19-5/8"X 7"TIEBACK SLV w/LNR HGR,ID=? 8160' H4-1/2"OTIS XN NP,D=3.725" il 11__________-- 8171' —14-1/2"BAKER BULLNOSE SHEA ROUT SUB 4-1/2"TBG-FC, 12.6#,L-80, .0152 bpf,ID=3.958" —I 8172' 8172' 14-1/2"TUBING TAL,D=3.958" —1 ELFv1D TT NOT LOGGED 9-5/8"CSG,47#,L-80 BTC,D=8.681" —{ 8437' • , PERFORATION SUMMARY REF LOG: BHCS 05/31/79 ANGLE AT TOP PERF: 27'@ 8988' Note:Refer to Production DB for historical pert data SIZE SFf PIIERVAL Opn/Sqz SHOT SQL 3-3/8" 4 8988-9280 0 '80&'87 3-3/8" 4 9298-9318 0 01/31/80 3-3/8" 4 9354-9404 0 01/31/80 7"LAR,29#,N-80 BTC, .0371 bpf,ID=6.184" —{ 9510' , DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/07/79 PKR 141 INITIAL COMPLETION 05/26/13 LAG PJC IA CEMENTED WELL: NGI-14 12/06/88 WWS 1 RWO PBZMT No: '1780920 01/05/11 D141 RWO API No. 50-029-20348-00 01/09/11 ?I PJC DRLG DRAFT CORRECTIONS SEC. 1,T11N,R14E,606'FSL&816'RM. 01/11/11 HB/PJC ANAL DRLG CORRECTIONS 02/11/11 M3/JMD AIMED SSSV SAFETY NOTE BP Exploration(Alaska) e , ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.3,DBR,LHD,cAZ 01/15/14) General Information Well Name: NGI-14 Well Type: Injector API Number: 500292034800 Well Activity Classification: Conventional 4 Activity Description: Water Wash Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR,bopd: Job Type: Water Wash Estimated Cost, $M: AWGRS Job Scope: PARAFFIN/ASPHALTENE REMOVAL Other regulatory requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Javier Farinez Contact numbers: 907-564-5043 907-947-5722 Well Intervention Engineer: Contact numbers: Lead Engineer: Javier Farinez Contact numbers: 907-564-5043 907-947-5722 Date Created: March 25,2014 Revisions(date,who,what changed): Current Well Status Information Recent WT or In)Rate&Pressure 3/24/2014 N/A N/A 220.MMscfpd N/A N/A N/A 3,400 psi Current Status: Operable If inoperable or under evaluation, why? N/A Recent H2S (date,ppm) N/A 0 ppm Maximum Deviation(angle and depth) 41° 7,300'MD Datum depth,ft TVDss 8,800'TVDss Minimum ID and Depth 3.725"@ 8,160' Reservoir pressure(date,psig) N/A 3,387 psi Reservoir temperature,F 130°F Shut in wellhead pressure 2,520 psi Known mechanical integrity problems(specifics) None Last downhole operation(date,operation) 8/16/2011.SSSV Maintenance Most recent TD tag,(date,depth,toolstring OD) 10/2/2010.9425'w/4-1/2"Brush 3.70"&Cent&S.Bailer Comments,well history, Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used er background information,etc: successfully in the past on the NGI/WGI/AGI gas injectors to improve infectivity. Well Intervention Details Suspected Well Problem: Oragnic deposition Specific Intervention or Well Objectives: 1 Increase well injectevity by cleaning the tubing and perforations 2 3 Key risks,critical issues: Mitigation plan: 1 2 3 Summary Step Service Line Activity 1 F Pump Water Wash as per schedule form 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production Rates: BOPD MMSCFD BWPD FTP(psi): Choke setting: Post job POP instructions: Bring back well to injection Attachments- include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission gg + DATE: Tuesday, April 05, 2011 TO: Jim Re a L( I i P.I. Supervisor ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI -14 FROM: Jeff Jones PRUDHOE BAY UNIT NGI -14 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry , NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT NGI -14 API Well Number: 50- 029 - 20348 -00 -00 Inspector Name: JeffJones Insp Num: mitJJ110313173645 Permit Number: 178 -092 -0 Inspection Date: 3/13/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI -14 - Type Inj. G :1- TVD 7059 ' IA 450 2030 . 2025 2025 - P.T.D 1780920 TypeTest SPT " Test psi 1765 - OA 0 20 20 20 T Interval OTHER P/F P - Tubing 3150 3150 3150 3150 Notes: 1.5 BBLS methanol pumped. 1 well inspected; no exceptions noted. Post RWO MITIA to cancel AA. - ` 'c rl App. 1 3 EZ1It' Tuesday, April 05, 2011 Page 1 of 1 1Q2011 Not Operable Injector Rep, Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, April 03, 2011 7:30 AM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 1Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 1Q2011.zip Tom, Jim, Phoebe and Guy, Attached is the 1Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 1Q2011.zip» 50 ) APR 1. 8 2011 Notes on wells: Removed from Quarterly Injection Report: 03 -37: TxIA comm. when on MI. Well placed on production to eval TxIA comm. while on water injection. NGI -14: RWO repaired TxIAxOA comm. on 01/05/11 U -04A: Startinghead leak mitigated with Furmanite wrap on 02/12/11 Added to Quarterly Injection Report: S -101: MIT -IA failed on 03/01/11. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 4/17/2011 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission gg DATE: Monday, March 14, 2011 TO: Jim Rp .1? _ "zJ j 1 P.I. Supervisor t ( SUBJECT: Mechanical Integrity Tests 6 BP EXPLORATION (ALASKA) INC NGI -14 FROM: Jeff Jones PRUDHOE BAY UNIT NGI -14 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry .1.6'0-- NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT NGI -14 ' API Well Number: 50- 029 - 20348 -00 -00 Inspector Name: JeffJones Insp Num: mitJJ110313173645 Permit Number: 178 -092 -0 Inspection Date: 3/13/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NG1 -14 f Type Inj. G r TVD 7264 ' IA 1 450 1 2030 ' 2025 1 2025 ' P.T.D 1780920 ' T y peTest SPT Test psi 1816 - ' OA 0 20 20 20 _ p Interval 4YRTST per, P , Tubing 3150 3150 3150 3150 Notes: 1.5 BBLS methanol pumped. 1 well inspected; no exceptions noted. Post RWO MITIA to cancel AA. % MAR 3 0 ZVI Monday, March 14, 2011 Page 1 of 1 STATE OF ALASKA j ALAS�IL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERA NS a 2011 1. Operations Performed: "'. °'el( A 'l!l 9 4 9 C0R5. Commission' ❑ Abandon IN Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ■=4 Alter Casing ®Pull Tubing 0 Perforate New Pool 0 Waiver 0 Other .- : - --pap ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory 178 - 092 3. Address: ® Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 • 50 - 029 - 20348 - 00 - 00 7. Property Designation: 8. Well Name and Number: ADL 28302 r e PBU NGI - 9. Field / Pool(s): Prudhoe Bay Field / Prudho Bay Oil Pool 10. Present well condition summary Total depth: measured 9515' feet Plugs (measured) None feet true vertical 8515' feet Junk (measured) None Effective depth: measured 9469' feet Packer. (measured) 7867' & 8096' feet true vertical 8474' feet Packer. (true vertical) 7067' & 7264' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 79' 79' Surface 2705' 13 -3/8" 2705' 2705' 4930 2670 Intermediate 8437' 9-5/8" 8437' 7559' 6870 4760 Production Liner 1374' 7" 8136' - 9510' 729 ,8' - 8511' 7240 5410 :: 1A4 MAR la 8 201 Perforation Depth: Measured Depth: 8988' - 9404' True Vertical Depth: 8044' - 8415' Tubing (size, grade, measured and true vertical depth): 7 - 5/8 ", 29#x7" 26# L -80 7991' & 7174' & 4 12.6# 8136' - 8172' 7298' - 7329' Packers and SSSV (type, measured and true vertical depth): 9 x 7" Baker 'S packer; 7867' 7067' 9 x 7" BKR'FB - 1' Packer 8096' 7264' 11. Stimulation or cement squeeze summary: , D (- "P/`°` CQL_ c.s cam G� Intervals treated (measured): 7 „ C,.... -' C,.... -' pp.....— ,.... -' a c4 s , p� • �— Q� ` €M /04.e4cc -� ;s /too 4 bo„� 41.10 p ,:.-. , a • Treatment description including volumes used and final pressure: .7... 3 .7 - // Cut and pull tubing from - 8059'. Cut, pull and dress 9-5/8" Casing to - 2506'. Run 9-5/8" Tieback to 2509'. Cement tieback/(v/ 168 Bbls of Class 'G' cement (806 sx, Yield 1.17). Run new Completion to 7991'. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory ❑ Development 0 IN Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ® GINJ ❑ Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. 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: Contact Hank Baca, 564-5444 310 - 347 Printed Name Terrie Hubble Title Drilling Technologist nn / / Prepared By Name/Number. Signature 4 . j , Phone 564-4628 Date Tee Hubble, 564 -4628 Form 10-404 Revised 10/2010 SDMS MAR 0 201101401— Submit Original Only _L/371( NELLHEAD = MCEVOY NGI-14 I SAFETY TES: WELL REQUIRES A SSSV. 4CTUATOR = BAKER C <B. ELEV = 48' • I I 3F. ELEV = <OP = 3400' 20" CONDUCTOR. 110' , , 1 2199' H 7" CAMCO DB -6 NIP, ID = 6.00" I vlax Angle = 41° @ 7300' 94 #, H -40, Datum MD = 9884' ;'_ 2327' I� 9 -5/8" FOCI Datum TVD = 8800' SS ID = 19.1274" r `' 9 -5/8" CSG, 47 #, S00 -95 XO TO L -80 BTC H 2306' V a �1 2459' H 9 -5/8" FOC 1 19 -5/8" CSG, 47 #, L -80 HYD 563, ID = 8.68" H 2505' 2463' H9-5/8" HES CEMENTER I 2484' H 9 -5/8" BKR ISO -ZONE CSG PKR, ID = 8.75" I 9 -5/8" BOWEN CSG PATCH, ID = 9.85" H 2505' - 2509' 13 -3/8" CSG, 72 #, N -80 BUTT, ID = 12.347" H 2709' --I 7778' 1-17-5/8" X 7" XO, ID = 6.276" I 7 -5/8" TBG, 29 #, L -80 VAM TOP HC IPC, H 7778' I 7836' H 7" HES "R" NIP, ID = 5.963" 0459 bpf, ID = 6.875" Minimum ID = 3.725" @ 8160' S X I 7867' H9-5/8" X 7" BKR S -3 PERM PKR, ID = 6.00" I 4-1/2" OTIS XN NIPPLE • • I 7901' H7" HES "R" NIP, ID = 5.963" I 1 I 7973' HT HES "RN" NIP, ID = 5.77" I 7" TBG, 26 #, L -80 VAM TOP HC, —I 7991' . ■ 1 7991'1-17" WLEG, ID = 6.276" I .0383 bpf, ID = 6.276" 8096' H9-5/8" X 7" BKR FB -1 PKR, ID = 6.00" ■ 8111' H7-5/8" MILLOUT EXTENSION, ID = 6.687" I 8116' H7-5/8" X 4-1/2" XO, ID = 4.892" I I TOP OF 7" LNR H 8136' I-- --I 8136' H 9 -5/8" X 7" TIEBACK SLV w / LNR HGR, ID = ? I 8160' H4 -1/2" OTIS XN NIP, ID = 3.725" I 8171' H4 -1/2" BAKER BULLNOSE SHEAROUT SUB 1 -1/2" TBG -PC, 12.6 #, L -80, .0152 bpf, ID = 3.958 "i-1 8172' I 81 H4 -1/2" TUBING TAIL, ID = 3.958" I I H ELMD TT NOT LOGGED I 19 -5/8" CSG, 47 #, L -80 BTC, ID = 8.681" I—I 8437' 1 • ■ PERFORATION SUMMARY REF LOG: BHCS 05/31/79 ANGLE AT TOP PERF: 27° @ 8988' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 8988 - 9280 0 '80 & '87 3 -3/8" 4 9298 - 9318 0 01/31/80 3 -3/8" 4 9354 - 9404 0 01/31/80 17" LNR, 29 #, N -80 BTC, .0371 bpf, ID = 6.184" I-J 9510' I A{ 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/07/79 PKR 141 ORIGINAL COMPLETION WELL: NGI-14 12/06/88 WWS 1 RWO 1 PERMIT No: '1780920 01/05/11 D141 RWO API No: 50- 029 - 20348 -00 01/09/11 ? / PJC DRLG DRAFT CORRECTIONS SEC. 1, T11N, R14E, 606' FSL & 816' FWL 01/11/11 HB /PJC FINAL DRLG CORRECTIONS n9/11 MP /.IMrl 4 CAPPTY N.IcTP RPFvnInratinn /Alacteal • RWO, Well History (Pre Rig Workover) Date Summary 11/13/2010 T /I /O= SSV /150/100 Temp =SI PPPOT-T (PASS) PPPOT -IC (PASS) (Pre RWO) PPPOT -T : RU 1 HP BT onto THA 150 psi bled to 0 psi. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 30 minutes. Bled void to 0 psi, RD test equipment, re- installed Alemite caps, cycle LDS "Standard" (1/2 ") all were in good working and visual condition. PPPOT -IC : RU 1 HP BT onto IC test void 0 psi. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi, RD test equipment, re- installed Alemite caps, cycle LDS "Standard" (1/2 ") (1) pin @ 9:00 left in the out position, all others were in good working and visual condition. * ** LDS on BTM of tubing spool all cycled out 3/4" and ran in Alignment pin functioned as well * ** 12/8/2010 WELL S/I ON ARRIVAL. EQUALIZED & PULLED 4 -1/2" XXN PLUG BODY FROM 8,135' SLM / 8,160' MD. LRS CURRENTLY RIGGING UP HARDLINE TO LOAD & FREEZE PROTECT TUBING. 12/9/2010 LOAD TBG W/ 505 BBLS OF 1% KCL & FREEZE PROTECT W/ 100 BBLS OF 60/40 METH. SET 4 -1/2" WFD WRP (3.77" od / 3.77' = oal) (a7 8,150' MD. LRS PERFORMED SUCCESSFUL MIT -T TO 2500 PSI. DUMP -BAIL 2 -BAGS SLUGGITS ON WRP @ 8150' MD. SET 3.75" x 114" JUNK CATCHER ON W SLUGGITS, TOP OF FISHING NECK @ 8100' SLM. WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 12/11/2010 T /I /O= 1050/170/30. T, IA, OA FLs (Pre- CTD). TBG FL @ 500', IA FL near surface, OA FL @ surface (arctic pack). 12/12/2010 WELL SHUT -IN ON ARRIVAL. PDS CONDUCT A BASELINE PASS TO 4000'. LRS BEGIN PUMPING ON IA. PDS CONDUCT 30 FPM DYNAMIC PASS FOLLOWED BY 10 FPM PASSES OVER 2,600' TO 2,800' AND 100' TO SURFACE INTERVALS. DETECT LEAK ANOMALY AT 2472. RIGDOWN PDS AND LRS STOP PUMPING. RIH AND PUNCH TUBING AT 8050' TO 8054' INTERVAL WITH 1.56 " 20 DM TUBING PUNCH. 12/13/2010 INITIAL T /IA/OA = 1500/250/0 PSI. S. • : ► • ► . :1 1 - :. OOD INDICATION OF HOLES PUNCHED. CONFIRMED BY LRS. FINAL T /I /O = 600/444/444 PSI. WELL LEFT SHUT IN AND TURNED OVER TO LRS, DSO NOTIFIED. JOB COMPLETE. 12/14/2010 T /I /0= 10/0/0 +. Temp =SI. TBG, IA, OA, FL's (Fullbore). TBG FL @ 234' (9 bbls), IA FL @ 270' (7 bbls), OA FL © 78' (4.5 bbls). 12/14/2010 T /I /O= 100/200/0 Circ- out TBGx IA x OA / CMIT Tx IA x OA to 2500 Psi Passed (Pre - Rig). Freeze protect TBG with 8 bbls diesel. Pump 170 bbls 9.8 brine down IA taking returns up OA to tiger tank to Circ -Out. Triple CMIT Passed on 2nd test. Pump 23 bbls diesel to achieve test press of 2500 Psi. T /I /O lost 40/60/50 Psi in 1st 15 Min and lost 20/20/50 in 2nd 15 Min for a total Toss of 60/80/10 in 30 Min test. (Passed) Bleed WHP'S to 0 Psi. 12/14/2010 T /I /O= 0 +/0/0 +. Temp= SI. T, IA, OA FL (Pre -CTD). TBG, IA FL unchanged overnight. OA FL 126' (night shift). 12/15/2010 T /I /O =0/0/0 (PT BPV to 1000 Psi Passed) Pump 25 bbls diesel down IA to pressure up 1000 psi to test BPV. Monitor for 10 mins. Bled WHP to 0 PSI. FWHP= 0/0/0 12/15/2010 T /I /O = 2/0/0 Verified barriers the set a Grey 6" BPV. Tagged at 116" using one 18" extension. PT tree cap to 500 PSI (PASS). 12/16/2010 T /I /O= BPV /0/15. Temp = SI. WHPs. OAP increased 15 psi overnight. Well house removed. Tie in crew on location, in control of well. Page 1 of 1 • • kart America - ALASKA f DP Paget 0t22 Operation S IMMary Rep° Common Well Name: NGI -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 End Date: X4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 ; Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15 : 14 5/14/1979 00:00 @48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/18/2010 12:00 - 17:30 5.50 MOB P PRE MOBILISE RIG FROM WGI-06 TO NGI-14. PJSM WITH PEAK & CREW. MOVE ROCK WASHER, PIPE SHEDS, BOILERS, MOTOR COMPLEXES AND STAGE ON END OF WGI PAD. MOVE PUMP AND PIT COMPLEXES. PULL SUB OFF OF WGI -06. MOVE SUB, PIT AND PUMP COMPLEXES TO NGI AND STAGE. 17:30 - 21:00 3.50 MOB P PRE - MOVE MOTOR AND BOILER COMPLEXES TO NGI PAD AND STAGE. 21:00 00:00 3.00 MOB P PRE ' SUB FROM ENTANCE OF NGI PAD AND _ I _ SPOT SUB OVER NGI -14. _ 12/19/2010 00:00 - 10:00 10.00 MOB P PRE SPOT PIT, PUMP, MOTOR AND BOILER 1 COMPLEXES. SPOT PIPE SHEDS. WORK ON THE RIG ACCEPTANCE CHECK LIST. HOOK UP ALL ELECTRICAL AND SERVICE LINES BETWEEN THE MODULES. TURN ON THE ,STEAM, WATER, AND AIR HEATERS. LOWER 1 THE PIPE SKATE RAILS, BERM THE ROCK WASHER, AND ASSEMBLE MUD LINES. ACCEPT RIG AT 10:00 HRS 12/19/10 10:00 - 10:30 0.50 MOB P j i PRE PJSM ON RIG UP CIRCULATING LINES FROM WELL TO OUTSIDE TANK. PRESPUD MEETING WITH NEUHARTH CREW. 1 10:30 - 12:00 1.5a . MOB P PRE RIG UP LINES FROM WELL HEAD TO OUTSIDE TANK. PREPARE DSM EQUIPMENT. LOAD LUBRICATOR INTO PIPE SHED. 12:00 - 12:30 0.50 MOB P PRE 1 PJSM ON RIGGING UP DSM. ' PRESPUD MEETING WITH MORGAN (FILL -IN DRILLER SHUMWAY) CREW. _ 12:30 - 16:00 3.50 WHSUR P DECOMP TEST BARRIERS ON TREE WITH DIESEL TO 500 -PSI. RIG DOWN TEST LINES. RIG UP DSM LUBRICATOR. TEST LUBRICATOR AGAINST TREE MASTER VALVE TO 300 PSI LOW AND 3500 PSI HIGH FOR FIVE CHARTED MINUTES EACH PRESSURE. PUMP SSV OPEN AND FLUSH BPV WITH FRESH WATER. CONFIRM � 0 -PSI ON TUBING. PULL BPV. CLOSE MASTER VALVE AND LAY DOWN LUBRICATOR. 16:00 - 17:00 1.00 KILLW P DECOMP , PJSM. RIG UP LINES TO DISPLACE FREEZE PROTECT PER WELL PLAN. 17:00 - 20:30 3.50 KILLW P DECOMP RFVFRSF CIRCULATF 98 RBI S 9 A -PPG BRINE Ca 3.5 -BPM THROUGH CHOKE TAKING RETURNS TO OPEN TOP TANK. SWAP VALVE LINE UP AND CIRCULATED 55 -BBLS. @ 3.5 -BPM TAKING RETURNS FROM VA THROUGH CHOKE TO OPEN TOP TANK. SHUT DOWN PUMPING AND BLEW DOWN LINES TO OPEN TOP TANK. CIRCULATE SURFACE TO SURFACE WITH 9.8 -PPG BRINE. @ 6.0 -BPM AT 730 -PSI TAKING RETURNS TO RIG PITS. AT END OF CIRCULATION BRINE WEIGHT 9.8 -PPG IN AND 9.8 -PPG OUT. MONITORED WELL FOR FLOW FOR 30- MINUTES. NO FLOW NOTED. Printed 3/3/2011 2:04:45PM CO rth America- - ALASKA, BP O peration Surmar^y Rep Common Well Name: NGI -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 End Date: X4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15 : 14 5/14/1979 00:00 ©48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth ! Phase Description of Operations (hr) (ft) 20:30 22:00 1.50 KILLW P DECOMP TSIMOPS: RIG DOWN CIRCULATING LINES FROM TREE. LOADED 270 JTS. DP IN PIPE I SHED. LOADED WIRELINE LUBRICATOR AND LUBRICATOR EXTENSION IN PIPE SHED. CHANGED OUT WIRE LINE ON SUPER TUGGER. 22:00 - 00:00 2.00 DHB P DECOMP PJSM. PICK UP WIRELINE TOOLS TO RIG FLOOR. 12/20/2010 100:00 - 05:30 5.50 DHB P DECOMP a E LUBRICAIOR i IEXTENSION TO 7" OTIS QUICK CONNECT ON TOP OF SWAB VALVE. PICK UP UPPER SLICKLINE SHEAVE ON TRAVELING BLOCK BAILS. THREAD WIRELINE THROUGH LUBRICATOR. RIG UP FOLLOWING SLICKLINE LUBRICATOR COMPONENTS TO LUBRICATOR EXTENSION: 7" PUMP -IN SUB, DUAL WIRELINE BOPS, LUBRICATOR AND PACKOFF HEAD. CONNECT HYDRAULIC ,CONTROL LINES FROM SLICKLINE UNIT TO DUAL BOP'S. CONNECT HYDRAULIC CONTROL LINE FROM SLICKLINE UNIT TO 1 SSV. PRESSURE TEST UPPER BOP TO 250 -PSI LO/4000 -PSI PER SWS L REQUIREMENTS. LOWER BOP STUMP TESTED IN SWS SHOP. PICK UP 6.05" !GAUGE RING. PRESSURE TEST LUBRICATOR TO 250 -PSI HI/4000 -PSI HI FOR 5 CHARTED MINUTES EACH PRESSURE. ATTEMPT TO OPEN SWAB VALVE. VALVE IS PRESSURE LOCKED. CALLED FOR GREASE CREW TO BLEED PRESSURE OFF VALVE. BLED PRESSURE OFF SWAB VALVE. 1 OPENED SAME. 05:30 - 11:30 6.00 DHB P DECOMP 1 RIH WITH 6.05" GAUGE RING, HELD UP AT 73'. MADE SEVERAL ATTEMPTS TO PASS OBSTRUCTION. NO SUCCESS. LAY DOWN 1 GAUGE RING. RIH WITH 5.5" BRAIDED WIRE BRUSH TO 100'. NO OBSTRUCTIONS. LAY DOWN BRUSH 1 RIH WITH 4 PRONG 6.05" WIRE GRAB TO 350'. 1 NO OBSTRUCTIONS. LAY DOWN WIRE GRAB. RIH WITH 6.05" GAUGE RING TO 350'. NO OBSTRUCTIONS. LAY DOWN GAUGE RING. RIH WITH BAKER 5 97" OD WIRELINE SET, RBP WITH HALLIBURTON RUNNING TOOL ON SWS SLICKLINE AND SET AT 217'. GOOD ;SURFACE INDICATION OF SET. PICK UP 10', I RIH AND TAG RBP ON DEPTH. POH WITH RUNNING TOOLS. LAY DOWN 1 RUNNING TOOLS. 11:30 13:00 1.50 DHB P DECOMP RIG UP LINES TO TEST RBP. PJSM WITH CREW ON PRESSURE TEST TEST RBP TO 4000 PSI FOR 5 MINUTES FROM ABOVE. GOOD TEST. / TEST RBP TO 1000 PSI FOR 5 MINUTES FROM BELOW DOWN THE IA AND UP THE TUBING 113:00 - 16:30 3.50 DHB P DECOMP RIG DOWN SCHLUMBERGER SLICK LINE UNIT, BOP AND LUBRICATOR AND I LUBRICATOR EXTENSION. REMOVE TOOLS FROM THE RIG FLOOR. Printed 3/3/2011 2:04:45PM tct Arnenca - ALASKA Bf Oz,i,.i Pages S t peiratiot Summary Report Common Well Name: NGI -14 AFE No Event Type: WORKOVER (WO) ! Start Date: 12/10/2010 End Date: JX4 -00RXG (3,205,000.00 ) I Project: Prudhoe Bay (various) Site: NGI j Rig Name /No.: DOYON 141 Spud Date/Time: I Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15:14 5/14/1979 00:00 ©48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (ft) 16 :30 - 21:00 4.50 WHSUR P DECOMP NIPPLE DOWN 7 1/16" TREE AND ADAPTOR SPOOL. SPLIT INTO THREE PARTS AND I REMOVE FROM CELLAR 21:00 - 00:00 3.00 BOPSUR P DECOMP � NIPPLE UP BOPE AND INSTALL SECOND t3 -1/8" FLANGED GATE VALVE ON VA. CHANGE UPPER PIPE RAMS FROM 7 -5/8" FIXED TYPE TO 7" FIXED RAMS. NOTIFIED jAOGCC,OF IMPENDING INITIAL BOPE TEST. JEFF JONES, AOGCC INSPECTOR, WAIVED STATES RIGHT TO WITNESS BOPE TESTING. 12/21/2010 00:00 - 03:30 3.50 BOPSUR P DECOMP ,CONTINUE'NIPPLING UP BOPE. CHANGE UPPER PIPE RAMS FROM 7 -5/8" FIXED TYPE ITO 7" FIXED TYPE PICK UP 7" TEST JOINT 1 WITH7`' BUTTRESS XO AND SCREW INTO iTUBING HANGER. 03:30 - 10:00 6.50 BOPSUR P DECOMP j RIG UP TEST EQUIPMENT. TEST BOPE PER � BP /AOGCC REQUIREMENTS TO 250 -PSI � ' LO /4000 -PSI HI AND AND CHARTED MINUTES Q � EACH PRESSURE. TESTED PIPE RAMS WITH 5o I 4 AND 7" TEST JOINTS. TESTED ANNULAR ! ; PREVENTER WITH 4" AND 7" TEST JOINTS. e ;ACCUMULATOR TEST. OK RIG DOWN TEST LINES. BLOW DOWN {CHOKE AND LINES. ,10:00 - 11:30 1.50 DHB P DECOMP I PICKUP BAKER 7" RBP RETRIEVING TOOL. I RIH ON 7JTS. 4" DRILL PIPE TO 217'. CLOSE { ITIW VALVE ON LAST JT. BEFORE ENGAGING RBP. SCREW INTO TIW VALVE WITH TOP DRIVE AND CLOSE ANNULAR PREVENTER. ' ENGAGE RBP AND OPEN EQUALIZING VALVE. OPEN TIW VALVE AND CHECK FOR PRESSURE ON DRILL PIPE. NO PRESSURE , ON DRILLPIPE. PICK UP ON PLUG AND CHECK FOR PRESSURE ON ANNULUS. NO I ` PRESSURE ON ANNULUS. OPEN ANNULAR PREVENTER. POH AND LAY DOWN TOP , JOINT 4" DRILLPIPE AND STAND 2 STANDS DRILLPIPE IN DERRICK. I I HELD KICK WHILE TRIPPING DRILL (01) 11:30 - 12:00 0.50 DHB P DECOMP CLEAR AND CLEAN RIG FLOOR. 12:00 - 13:30 1.50 FISH P DECOMP MAKEUP BAKER 5- 1 /2 "_MULTISTRING.CASING_ GLUIER BHA #l____ HELD KICK W HILE TRIPPING DRILL (01) 13:30 - 19:45 6.25 FISH P DECOMP RIH WITH BHA #1 ON 4" XT -39 DRILL PIPE 1 X 1 FROM PIPESHED TO 8020' MD. 19:45 - 20:00 0.25 FISH P DECOMP PUMP TO OPEN CUTTER BLADES. RUN IN HOLE AND LOCATE TUBING COLLAR AT 8039' MD. LOCATE PUP JOINT COLLAR AT 8079'. oGc TAG UP AT 8085' ON CROSSOVER. -".bbd - 76 GPM, 200 PSI 20:00 - 20:30 0.50 FISH P DECOMP PICKUP TO 8059' MD TO SPACE OUT FOR TUBING CUT. - PU 133K, SO 127K CUT 7" TUBING AT 264 GPM. OBSERVE PRESSURE DROP FROM 1600 PSI TO 900 PSI AND TORQUE REDUCTION FROM 4K TO 2K, l END CUTTING. Printed 3/3/2011 2:04:45PM o meti .-AtAsKA BP Pligit4 Operation Summary; Report Common Well Name: NGI -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 End Date: X4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15:14 5/14/1979 00:00 @48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 - 20:45 0.25 FIS j P DECOMP BLOW DOWN TOP DRIVE. RIG UP TO REVERSE CIRCULATE THROUGH SUPER CHOKE. 20:45 - 21:45 1.00 FISH P DECOMP CIRCULATE BOTTOMS UP THROUGH SUPER ' CHOKE. PUMP DOWN 9 -5/8" X 7" ANNULUS. TAKE RETURNS UP 7" X 4" DP ANNULUS. - 168 GPM, 300 PSI 21:45 - 22:00 0.25 FISH P DECOMP j MONITOR WELL VIA GAS BUSTER. OPEN ANNULAR PREVENTER, MONITOR WELL - STATIC. ' I BLOW DOWN LINES AND CHOKE MANIFOLD. 22:00 - 00:00 2.00 FISH P DECOMP PULL OUT OF HOLE FROM 8059' MD TO 3391' MD RACKING BACK 4" ©P STANDS. 12/22/2010 00:00 - 01:30 1.50 FISH P DECOMP PULL OUT OF HOLE FROM 3391' MD TO BHA, RACKING BACK 4" DP STANDS. WHEN RACKING BACK LAST STAND OF DRILL PIPE IT WAS FOUND THAT A DISCREPANCY IN JOINT COUNT EXISTED. THE JOINT COUNT WAS 1 JOINT SHORT. DEPTHS CORRECTED TO REFLECT DISCREPANCY. 01:30 - 02:00 ! 0.50 FISH P DECOMP "-LAYDOWN BAKER 5 -1/2" MULTISTRING CASING CUTTER. CLEAN AND CLEAR RIG FLOOR. PULL P DECOMP 02:00 - 03:00 1.00 HOLD PJSM. PICK UP SPEAR AND MAKE UP SPEAR ASSEMBLY. BACK OUT LOCK DOWN 'SCREWS. I � j HELD WELL CONTROL DRILL AND CONDUCTED AAR. 03:00 - 06:00 3.00 PULL P DECOMP SPFAR HAN(FR AND BRFAK FRFF AT 751K PULL HANGER TO SURFACE. RELEASE 1 SPEAR AND LAY DOWN HANGER. RIG UP TO CIRCULATE. PUW 205K _ 06:00 - 08:30 1 2.50 PULL P DECOMP MAKE UP SAFETY VALVE AND CROSSOVERS TO 7" TUBING. CIRCULATE BOTTOMS UP THROUGH SUPER CHOKE. PUMP AT 210 GPM, 200PSI. STAGE PUMPS UP TO 420 GPM, 550 PSI. MONITOR WELL - STATIC. RID DOWN CIRCULATING EQUIPMENT. BLOW DOWN LINES. - P DECOMP HOLD PJSM 08 30 09:00 i 0.50 PULL PJSM, RIG UP CONTROL LINE SPOOLING UNIT. CHANGE OUT ELEVATORS TO 7 ". j HELD KICK WHILE TRIPPING DRILL (D1) Printed 3/3/2011 2:04:45PM Airier -- >AfASKA BP of 22: Operation Siunn ary Report Common Well Name: NGI -14 j AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 End Date: `X4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 ' Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15:14 5/14/1979 00:00 @48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 09:00 - 19:00 10.00 PULL P DECOMP PULL OUT OF HOLE WITH 7" TUBING AND DUAL CONTROL LINES. LIGHT COATING OF I BLACK TAR LIKE RESIDUE BUILD UP ON OUTSIDE OF FIRST 55 JTS OF TUBING. TERMINATE CONTROL LINES ON JOINT 55 AND LAY DOWN SSSV. RECOVER 29 STAINLESS STEEL BANDS. CONTINU E -T O LAY DOWN A TOTAL OF 202 JTS AND CUT JOINT OF LENGTH 20.89'. ON CUT'JOINT, OBSERVE TUBING PUNCHES FROM 2.10' TO 6.30' FROM COLLAR. 19:00 - 20:00 1.00 PULL P DECOMP RIG DOWN CASING HANDLING EQUIPMENT. LAY DOWN SAME. 20:00 - 21:30 1.50 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR. 21:30 22:00 0.50 PULL P DECOMP EXPEDITE; BHA COMPONENTS TO RIG FLOOR. CHANGE OUT HANDLING TOOLS TO 22:00 - 23:15 1.25 j PULL P DECOMP HOLD PJSM, MAKE UP BHA WITH SPEAR, L BUMPER SUB, JARS AND 6 114" DRILL COLLARS. 23:15 - 23:30 0.25 PULL P DECOMP LCHANGE OUT HANDLING TOOLS TO 4". { . HELD KICK WHILE TRIPPING DRILL (D1) 23:30 - 00:00 0.50 PULL P DECOMP 1 SERVICE RIG. LUBRICATE TOP DRIVE, DRAWWORKS AND RIG COMPONENTS. 12/23/2010 00:00 - 03:30 3.50 PULL P 1 DECOMP RUN IN HOLE WITH FISHING BHA ON 4" DP. SERVICE TOP DRIVE, TOP DRIVE UNABLE TO ROTATE DUE TO VARIABLE FREQUENCY DRIVE BEING BELOW OPERATING TEMPERATURE RANGE. 03:30 - 04:30 1.00 PULL P DECOMP 1 ENGAGE SPEAR ON LOCATOR SEAL ASSEMBLY W/ 10K DOWN. FIRE JARS 4 —� TIMES TO RELEASE SEAL ASSEMBLY. OVERPULLS RANGING FROM 50K - 150K. 04:30 - 08:30 4.00 PULL P DECOMP RACK BACK ONE STAND AND CIRCULATE 1.5 BOTTOMS UP TAKING RETURNS THROUGH CHOKE. PUMP AT 4 -7 BPM, 300 -750 PSI 1 MONITOR WELL - OUT OF BALANCE. CIRCULATE ANOTHER BOTTOMS UP BPM 1800 PSI THROUGH FLOWLINE. SHUT 1 DOWN AFTER CIRCULATING AND MONITOR WELL - STATIC. 08:30 - 12:15 3.75 PULL P DECOMP '' BLOW DOWN CIRCULATING LINES. PULL OUT OF HOLE FROM 8,028' MD TO BHA AT 222' MD. 12:15 13:00 0.75 PULL P DECOMP MONITOR WELL - STATIC. RACK BACK DRILL ! COLLARS. LAY DOWN JARS AND SEAL LOCATOR ASSEMBLY. 13:00 13:15 0.25 PULL P i DECOMP CLEAN AND CLEAR RIG FLOOR. - ;13:15 14:45 1.50 PULL P DECOMP HOLD PJSM, BRING E -LINE EQUIPMENT TO 1 RIG FLOOR. RIG UP E -LINE EQUIPMENT. Printed 3/3/2011 2:04:45PM Arlie - ALASKA BP P 8 of 22 f E plerat'on Summary Report Common Well Name: NGI -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 j End Date: X4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: _ Active Datum: 15:14 5/14/1979 00:00 @48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 14:45 - 20:00 5.25 PULL P () DECOMP RUN 8.482" GUAGE RING AND JUNK BASKET. T AG OBSTRUCTION AT 2321' E -LI DEPTH. DECISION MADE TO PULL OUT OF HOLE WITH E - JUNK BASKET EMPTY BUT COVERED WITH LIGHT COAT OF BLACK TAR LIKE SUBSTANCE. Us - RUN USIT LOG IN HOLE TO 2800' AND LOG TO SURFACE. TOP OF CEMENT AT 2550' FROM LOG. 20:00 - 20:45 0.75 PULL P DECOMP RIG DOWNE-LINE EQUIPMENT AND LAY DOWN. CHANGE OUT TO 4" HANDLING [ TOOLS. 20:45 - 21:30 0.75 PULL P DECOMP HOLD PJSM, MAKEUP 9 -5/8" RETRIEVABLE BRIDGE PLUG AND SETTING TOOL. 21:30 - 23:00 1.50 PULL P DECOMP RUN IN HOLE ON 4" DP TO 2 59f1' MD.WITH I 9 -5/8" RBP 23:00 - 23:30 0.50 PULL P DECOMP SET 9-5/8" RBP. RELEASE OFF AND TAG WITH 15K'TOCONFIRM RBP SET. PUW 68K, SOW 56K 23:30 - 00:00 0.50 PULL P DECOMP TEST 9-5/8" RBP TO 1000 PSI FOR 10 - CHARTED MINUTES. 1000 PSI OBSERVED ON 13 -3/8" X 9-5/8" ANNULUS. BLEED ANNULUS TO 0 PSI AFTER TEST. HELD KICK WHILE TRIPPING DRILL (D1) 12/24/2010 00:00 - 00:30 0.50 PULL P { DECOMP BRING DRILL PIPE SAND HOPPER AND SUPER SACK OF BAGGED 20/45 MESH SAND I TO RIG FLOOR. 00 :30 - 03:00 2.50 PULL P DECOMP DUMP 2200 -LBS. (52) OF 20/45 MFSH SAND ON TOP OF 9 -5/8" RBP USING DRILL PIPE _ 1 SAND HOPPER. 03:00 - 03:30 0.50 PULL P DECOMP CIRCULATE DRILL PIPE VOLUME TO CLEAR DRILL PIPE OF SAND. ' - 2 BPM, 80 PSI 03:30 - 04:30 1.00 PULL P DECOMP PULL OUT OF HOLE WITH RBP RUNNING TOOL AND LAY DOWN SAME. _ 04:30 - 05:30 1.00 PULL P DECOMP CLEAR AND CLEAN RIG FLOOR. 05:30 - 08:00 2.50 PULL P DECOMP (MAKE UP 9-5/8" BAKER MULTI - STRING ■ CASING CUTTER BHA ( #5) AND RUN IN HOLE. TAG TOP OF SAND AT 2532'. PICK UP 20' AND ESTABLISH PARAMETERS, P/U WT. = 64K, S/O WT. = 64K, ROT. WT. = 68K @ 60 AND 80 RPM, TQ = 2K FT -LBS., 58 SPM @ 500 -PSI, 75 SPM @ 800 -PSI AND 88 SPM @ 1000 -PSI. 08:00 - 09:15 1.25 PULL P DECOMP ;TAG TOP OF SAND AT 2532'. ENGAGE 1 PUMPS AND LOCATE LOWER CASING COLLAR AT 2522'. LOCATED UPPER CASING COLLAR AT 2481'. STAND BACK ONE STAND DRILLPIPE. PICKED UP 14' DRILLPIPE PUP JT. SPACED OUT CUTTER BLADES AT 2493'. 09:15 - 09:45 0.50 PULL P DECOMP I CUT 9 -5/8" CASING AT 2493' MD. STAGE PUMPS FROM 500 -PSI TO 1000 -PSI, ROTATING AT 60 -RPM WITH 2K TQ. STAGED UP TO 80 -RPM WITH 4-6K TQ. PUMP PRESSURE DECREASED TO 920 -PSI AND TQ. _ _ ! DECREASED TO 2K FT -LBS. 09:45 - 10:00 0.25 PULL P DECOMP BLEW DOWN TOP DRIVE. MIRU LRS TO CEMENT LINE. Printed 3/3/2011 2:04:45PM rt1 Arnerica - ALASKA SPA Page i of operation Summery Report z, Common Well Name: NGI -14 AFE No Event Type: WORKOVER (WO) I Start Date: 12/10/2010 End Date: X4 -O0RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: Rig Contractor DOYON DRILLING INC. UWI: Active Datum: 15 : 14 5/14/1979 00:00 @48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) T 10:00 - 11:15 1.25 PULL P DECOMP PJSM. LRS PUMP 24 -BBLS. 120F DIESEL DOWN DRILL PIPE TAKING RETURNS TO RIG PITS. CLOSED ANNULAR PREVENTER, OPENED O/A AND PUMPED ADDITIONAL 27 -BBLS. DIESEL DOWN DRILL PIPE. TAKING RETURNS TO TIGER TANK THROUGH CHOKE MANIFOLD. PUMPED AT 2.0 -BPM AT 200 -PSI INCREASING TO 450 -PSI. SHUT DOWN. 'PUMPED 27 -BBLS. 120F 9.8 -PPG BRINE WITH 1 TO 1 RATIO ON CIRCULATION. 11:15 - 12:30 1.25 PULL P DECOMP I LET DIESEL SOAK FOR 1 -1/4 HRS. 12:30 - 13:45 1.25 PULL P i. DECOMP PJSM . -CBU TAKING RETURNS TO TIGER TANK. INITIAL PUMP RATE @ 3.5 -BPM @ 80 -PSI. STAGED PUMP UP TO 8.5 -BPM @ 1825 -PSI. PUMPED 45-BBL. SAFE - SURF -O PILL SURFACE TO'SURFACE AT 8.5 -BPM @ 1825- PSI RETURNS TO TIGER TANK. UNABLE TO DETERMINE ARCTIC PACK CONTENT IN FLUID RETURNS GOING INTO TIGER TANK. 13:45 - 14:00 0.25 PULL -- P DECOMP BLOW DOWN LINES AND TIGER TANK LINES. - T OPEN ANNULAR PREVENTER. NO FLOW I NOTED FROM WELL. 14:00 - 15:00 1.00 PULL P DECOMP; "I� - PUMP 45 -BBL. SAFE-SURF-0 PILL SURFACE TO SURFACE AT INITAL RATE OF 6 -BPM AND FINAL RATE OF 9 -BPM @ 1700 -PSI. DUMPED SAFE- SURF -O PILL TO ROCKWASHER. 15:00 - 15:30 0.50 PULL P DECOMP BLOW DOWN LINES, RIG DOWN HEADPIN IAND CEMENT LINE. LAY DOWN 14' PUP I JOINT AND SINGLE JOINT. 15:30 - 16:45 1.25 PULL P DECOMP I POH FROM 2493' AND LAY DOWN CASING CI ITTFR BHA ( #5) CUTTER BLADES SHOWED EVEN WEAR PATTERN INDICATIVE i OF A GOOD CUT. 16:45 - 18:30 1.75 PULL P DECOMP I PJSM. RIG FLOOR WITH 9 -5/8" CASING _ HANDLING TOOLS. 18:30 - 20:00 1.50 PULL P DECOMP PICK UP 9 -5/8" ITCO SPEAR WITH PACKOFF, 8.681" NOMINAL CATCH GRAPPLE AND STOP SUB ON SINGLE JOINT OF 4" XT -39 DRILLPIPE. SCREWED INTO JOINT WITH TOP DRIVE. BLED O/A TO0 -PSI FROM 100 -PSI. ENGAGE 9 -5/8" CASING WITH SPEAR. [ CAMERON WELLHEAD REPS. BACKED OUT LOWER LOCKDOWN SCREWS. PICKED UP TO 150K, STAGING UP TO 200K IN 25K INCREMENTS. SLACKED OFF TO 80K AND ,STAGE UP TO 225K UPWEIGHT. BREAK -P I. STAGE CATION 5.0 -BPM S �, CIRCU @ @ 250 PUMP TO 7.0 -BPM @ 450 -PSI. PICKED UP TO 250K, SLACKED OFF TO 100K, PICKED UP TO I 250K AND CASING BROKE FREE. PULLED CASING HANGER, CASING PACKOFF AND CASING TO FLOOR. SHUT DOWN PUMPING. CHECKED FOR FLOW. SLIGHT OUT OF BALANCE FLOW WHICH DIMINISHED TO NO FLOW IN ONE MINUTE. LAYED DOWN SPEAR AND SINGLE JOINT OF DRILLPIPE IN ONE PIECE INTO PIPESHED. Printed 3/3/2011 2:04:45PM aftwAmerica - ALASKA BP Page 8 of 2 Operation Summary Report' ' 1 i Common Well Name: NGI -14 I AFE No Event Type: WORKOVER (WO) I Start Date: 12/10/2010 End Date: f X4 -00RXG (3,205,000.00 ) I _ Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 1 Spud Date/Time: i Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15 : 14 5/14/1979 00:00 @48.00ft (above Mean Sea Level) Date 1 From - To Hrs Task 1 Code NPT NPT Depth Phase . Description of Operations (hr) (ft) 20:00 - 00:00 4.00 PULL ' P DECOMP FINISH RIGGING UP 9 -5/8" CASING TONGS. BROKE OUT AND LAYED DOWN CASING HANGER AND PACKOFF. MADE UP XO TO 9 -5/8" STUMP AND SCREWED INTO WITH TOP 1 1 I DRIVE. RECIPROCATED 9 -5/8" CASING AND CIRCULATED OUT ARCTIC PACK AT AN ( INITIAL PUMP RATE OF 5.0 -BPM @ 100 -PSI i - LAND STAGED PUMP UP TO 7.0 -BPM. CIRCULATED 40 -BBL. SAFE - SURF -O PILL SURFACE TO SURFACE TAKING RETURNS TO ROCKWASHER. P/U WT. =130K, S/O WT. I 1 = '.135K. RECOVERED AN EXTREMELY LARGE 1 AMOUNT OF ARCTIC PACK TO RIG PITS i WHILE .RECIPROCATING PIPE. EXACT BARREL COUNTOFARCTIC PACK RECOVERED UNKNOWN. 1 PICKED UP 9-5/8" SPEAR AND SINGLE JOINT 12/25/2010 00:00 - 00:30 0.50 PULL P DECOMP OF 4" DRILLPIPE AND BROKE OUT AND , 1 LAVED DOWN. �— — CASING, ' 6.50 �' PULL P � 00:30 - 07 :00 - DECOMP 'LAY D01NN 61 JTS OF 9 -5/8" CASING, 12.45' CUT JOINT AND CASING ACCESORIES: I -4 PUP JTS 1 - 2 F.O. COLLARS, LOWER F.O. COLLAR HAD 'PORTS FULLY OPEN - RECOVERED 18 BOW SPRING i ; CENTRALIZERS, LEFT IN WELL 3 BOW SPRING CENTRALIZERS AND BLADES AND TOP HALF OF CENTRALIZER COLLAR - 1 STEEL BAND 07:00 - 10:00 3.00 PULL P j DECOMP 1 LAY DOWN CASING TONGS. CLEAN AND CLEAR RIG FLOOR. DRAIN BOP STACK. OBSERVE 1/2 CENTRALIZER COLLAR IN RAM BODY, RECOVER CENTRALIZER COLLAR. SIMOPS: CLEAN PIT #6 AND TRIP TANK 10:00 - 14:00 4.00 PULL P DECOMP MONITOR WELL - STATIC. ALLOW CREWS EXTENDED MEAL TIME FOR HOLIDAY. 14:00 - 15:00 1.00 PULL 1 P DECOMP i PICKUP STACK WASHER. FLUSH BOP STACK WITH HEATED BRINE. LAY DOWN STACK WASHER. 115:00 - 15:30 0.50 PULL P DECOMP SERVICE TOP DRIVE, CHECK SWIVEL i _ PACKING, GREASE SAME. TEST TO 1000PSI. 15:30 - 17:15 1.75 CLEAN P I DECOMP I MOBILIZE TOOLS TO RIG FLOOR. MAKEUP DRESS -OFF ASSEMBLY WITH CASING I SCRAPER AND DRILL COLLARS. _ 17:15 - 18:00 0.75 CLEAN P DECOMP RUN IN HOLE WITH DRESS -OFF ASSEMBLY 1 TO 1628' 18:00 - 18:45 0.75 CLEAN P FDECOMP CIRCULATE BOTTOMS UP RECIPROCATING PIPE. - STAGE PUMPS UP TO 10 BPM, 400PSI I I - SIGNIFICANT PERCENTAGE OF ARCTIC _ _ PACK IN RETURNS 1 18:45 - 20:45 2.00 CLEAN j P DECOMP RUN IN HOLE TO 2097'. OFF LOAD FLUID FROM THE ROCK WASHER TO MAKE ROOM FOR CIRCULATING RETURNS. SIMOPS:BLOW DOWN TOP DRIVE. RECIPROCATE PIPE. Printed 3/3/2011 2:04:45PM tip c>`rth America - ALASKA BFI ! f perah© ,Summary Repor Common Well N ame: NGI -14 I AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 End Date: X4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 Spud Date/Time: I Rig Release: Rig Contractor: DOYON DRILLING INC. I UWI: Active Datum: 15 : 14 5/14/1979 00:00 ©48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (ft) 20:45 - 21:15 0.50 CLEAN P DECOMP I CIRCULATE BOTTOMS UP RECIPROCATING PIPE. ! - STAGE PUMPS UP TO 10 BPM, 400PSI ' - SIGNIFICANT PERCENTAGE OF ARCTIC PACK IN RETURNS 21 :15 - 22:00 0.75 CLEAN P 1 DECOMP RUN IN HOLE TO 2473'. PICK UP 4" DP SINGLE. TAG TOP OF CASING STUB ON DEPTH AT 2493'_ 22:00 - 22:30 0.50 CLEAN P j DECOMP . DRESS -OFF 9-5/8" CASING STUB. -10 BM, 450 PSI - 525 PSI -40 -70 RPM„ ERRATIC TQ 2K -14K 1 -PUW 75K, SOW 80K DRESS OFF PARAMETERS OUTSIDE OF ACCEPTABLE RANGE DECISION MADE TO PULL OUT OF AND LAY DOWN CASING SCRAPER. 22:30 - 23:00 0.50 CLEAN 1 P DECOMP PICK UP ABOVE CASING STUB AND CIRCULATE SAFE- SURF -O PILL SURFACE TO SURFACE RETURNS CLEANED UP WITH RETURN OF PILL. I ! ;MONITOR WELL - STATIC. 23:00 - 00:00 1.00 CLEAN P DECOMP LPULL OUT OF HOLE FROM 2473' TO 2100' 12/26/2010 '; 00:00 - 02:00 2.00 CLEAN P DECOMP I PULL OUT OF HOLE FROM 2100' TO SURFACE WITH DRESS -OFF ASSEMBLY. RACK BACK DRILL COLLARS. 02:00 - 03:00 1.00 CLEAN P DECOMP LAY DOWN CASING SCRAPER FROM BHA. INSPECT DRESS -OFF MILL. MAKE UP BHA AND RUN DRESS -OFF MILL AND DRILL COLLARS IN HOLE. 03:00 - 03:30 0.50 CLEAN P DECOMP I RUN IN HOLE TO 600' MD. 03:30 - 05:00 1.50 CLEAN P DECOMP I CUT AND SLIP 72' OF DRILLING LINE. I SERVICE TOP DRIVE. 05:00 - 06:15 1.25 CLEAN P DECOMP I RUN IN HOLE TO 9 -5/8" CASING STUB. - PUW 80K, SOW 75K HELD KICK WHILE TRIPPING DRILL (D1) 06:15 - 07:30 1.25 CLEAN P DECOMP BREAK CIRCULATION AND TAG 9 -5/8" CASING 1 STUB AT 2493'. POLISH CASING STUB AT 60 1 RPM AND 5 -1 OK TQ. 07:30 - 09:00 1.50 CLEAN N RREP DECOMP ,HOLD PJSM, CHANGE OUT SWIVEL PACKING AND TEST FOR LEAKS. TEST - GOOD. 109:00 - 09:30 0.50 CLEAN P DECOMP POLISH CASING STUB FROM 2496' -2497' WITH SAME PARAMETERS. OBSERVE SWIVEL PACKING LEAKING. 1 09:30 - 10:00 I 0.50 CLEAN N RREP I DECOMP TIGHTEN UP TOP NUT ON SWIVEL PACKING. I .. L - _ TEST FOR LEAKS. TEST - GOOD. Printed 3/3/2011 2:04:45PM 41 4 orth America - ALASKA - BP � a of 2 2 ' , ,,,,,, „ / , , , Operation Summary" Report Common Well Name: NGI -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 End Date: X4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15:14 5/14/1979 00:00 @48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 12 5 2.75 CLEAN P DECOMP POLISH CASING STUB FROM 2497' TO 2501'. MILLED AND DRESSED CASING STUB WITH INNER MILL FROM 2493' TO 2494'. NOTE METAL SHAVINGS COMING ACROSS THE C SHAKERS. WORK MILL OVER THE STUB WITH a ROTATION. TAG JUNK AT 2498'. MILL TO 2501' I - 250 GPM, 200 PSI 1- 70 RPM, 2-6K TQ SHUT PUMPS OFF AND STOP ROTATING. PICK OFF OF STUB AND SLACK OFF OVER STUB AND TAG ON DEPTH. . PUW 75K, SOW 83K., 12:45 - 13:45 1.00 j CLEAN P DECOMP CIRCULATESAFE- SURP -O PILL SURFACE TO SURFACE, - 336 GPM, 350 PSI STAGING UP TO 500 GPM, 675 PSI MONITOR' WELL - STATIC. BLOW DOWN TOP :DRIVE 13:45 - 15:30 1.75 CLEAN P DECOMP ; PULL OUT OF HOLE TO BHA. MONITOR WELL 1 - STATIC. CHANGE OUT HANDLING TOOLS TO 5" AND RACK BACK DRILL COLLARS. LAY DOWN BHA. - JUNK BASKET WAS COMPLETLY FILLED WITH METAL SHAVINGS 15:30 - 16:30 1.00 CLEAN P DECOMP 11 CLEAN AND CLEAR RIG FLOOR. LAY DOWN EXCESS TOOLS AND EQUIPMENT. BRING 1 CASING HANDLING EQUIPMENT TO RIG FLOOR. I 16:30 - 18:45 2.25 CASING P + DECOMP 1 RIG UP CASING RUNNING EQUIPMENT. T18:45 - 19:30 0.75 CASING P DECOMP I PICK UP CASING PATCH, EXTERNAL CASING PACKER, AND ES- CEMENTER. 1- BAKERLOK ALL CONNECTION BELOW ES- CEMENTER - MAKE UP ALL CONNECTIONS TO MARK 19:30 - 23:30 4.00 CASING C P DECOMP RUN 9 -5/8" CASING. - RUN 62 JTS OF 9 -5/8" HYRIL 563 L -80 47# - TORQUE TURN ALL CONNECTIONS TO 15,800 FT /LBS - USE JET LUBE SEAL GUARD ON ALL CONNECTIONS - RUN 1 STRAIGHT BLADED CENTRALIZER ON ALL JOINTS EXCEPT 62 Printed 3/3/2011 2:04:45PM •orth Arnerica-ALASKA-BP - IP ' f 1 of 22 i 0 ,-,,,,, , : ,, ,,,,,,,..,,, ,,,,-, paratiort,Summary Report. 1 Common Well Name: NGI -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 I End Date: X4 -OORXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI 1 Rig Name /No.: DOYON 141 Spud Date/Time: i Rig Release: Rig Contractor: DOYON DRILLING INC. _ 1 UWI: Active Datum: 15 : 14 5/14/1979 00:00 ©48.00ft (above Mean Sea Level) Date From - To l Hrs 1 Task Code ! NPT NPT Depth Phase Description of Operations 23:30 - 00:00 1 0 50 CASING P (ft) DECOMP TAG TOP OF 9 -5/8' CASING STUB. SWALLOW I CASING PATCH ONTO STUB. - PUW 126K, SOW 134K � , 1 "ATTEMPT PULL TEST TO 250K, CASING I PATCH DISENGAGED AT 200K. SLACK OFF 1 I AND ROTATE TO SWALLOW STUB AGAIN. I ATTEMPT PULL TEST TO 250K, CASING 1 - PAT(`H fJIS�NrAGEf) AT 150K SLACK OFF 1 I AND ROTATE TO SWALLOW STUB AGAIN. ATTEMPT PULL TEST TO 250K, CASING � {/ if, ...) j , 'PATCH DISENGAGED AT 126K (PICKUP { 1 WEIGHT). CASING PATCH NOT HOLDING. ESTABLISH CIRCULATION AND VERIFY CASING PATCH NOT HOLDING. CONSULT WITH ENGINEER IN ANCHORAGE. I DECISION' MADE TO PULL OUT OF HOLE _ WITH 9-5/8" CASING STRING. 12/27/2010 00:00 - 00:30 0.50 CASING P DECOMP BLOW DOWN TOP DRIVE AND PREPARE TO PULL 9 -5/8" CASING. 00:30 - 05:00 4.50 CASING P 1 ' DECOMP PULL OUT OF HOLE WITH 9 -5/8" 47 #, L -80 ; HYDRIL 563 CASING LAYING DOWN 1 X 1 I , I THROUGH PIPE SHED. (D1) KICK WHILE i- 1 TRIPPING DRILL CRT = 85 SECONDS. 05:00 - 06:00 1.00 CASING 1 P DECOMP BREAK BAKERLOK'D BUTTRESS CONNECTION ON ES- CEMENTER, EXTERNAL - I CASING PACKER, AND CASING PATCH. LAY DOWN SAME. 06:00 - 06:30 0.50 CASING P DECOMP � RIG DOWN 9 -5/8" CASING HANDLING TOOLS. , CLEAR RIG FLOOR. 06:30 - 07:30 1.00 FISH P ; DECOMP BRING BAKER FISHING BHA TOOLS TO RIG FLOOR. 07:30 - 11:00 1 3.50 FISH P 1 DECOMP MAKE UP WASHOVER BHA (#9) AS FOLLOWS: - SLICK ID DRAG TOOTH WASH SHOE 1 - 11 -3/4" WASH PIPE 1 - WASHOVER BOOT BASKET -XO 1 i - FLOAT SUB ! - 6 -1/4" LUBRICATED BUMPER SUB !- 6- 1 /4 " OIL JAR - PUMP OUT SUB - 6 -3/4" DRILL COLLARS 1 - 6 -1/4" INTENSIFIER - XO TROUBLESHOOT TOTCO MONITORING !SYSTEM. QUADCO TECH. REPAIRED SAME. I 11:00 - 12:00 1.00 I FISH P DECOMP ,RIH WITH BHA #9 TO 352' ON 4" XT -39 DRILLPIPE FROM DERRICK. 12:00 - 13 :30 h1.50 FISH P 1 DECOMP PJSM - TOUR CREW CHANGE. RIH TO 2419'. CORRECT DISPLACEMENT ON TRIP IN HOLE. I 1 ESTABLISH PARAMETERS: P/U WT. - 76K, 1 I S/O WT. - 81K, ROT WT. - 81K, FREE TQ. - 1-2K FT -LBS. BREAK CIRCULATION @ 4.0 -BPM © 120 -PSI. STAGE UP TO 6.0 -BPM © 220-PSI. -- - ! - - - - - - - - - -- I ___ _ 'TAG STU MP @ 2499'. -- Printed 3/3/2011 2:04:45PM North America - t.ASKA - BP rage 12 22 1 ip rati�ar� Sur>rma Report Common Well Name: NGI -14 I AFE No ■ Event Type: WORKOVER (WO) I Start Date: 12/10/2010 End Date: X4 -00RXG (3,205,000.00 ) ■ Project: Prudhoe Bay (various) I Site: NGI Rig Name /No.: DOYON 141 I Spud Date/Time: I Rig Release: 1 i Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15 : 14 5/14/1979 00:00 ©48.00ft (above Mean Sea Level) Date From - To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 15:45 2.25 FISH P DECOMP WASH OVER 9 -5/8" FROM 2499' TO 2522'. SMALL AMOUNT OF CEMENT IN RETURNS. RPM - 60, TQ. ON BOTTOM - 2 -5K FT -LBS. I I TAGGED 9-5/8" CASING COLLAR AT 2522'. 15:45 - 16:45 !; 1.00 FISH P DECOMP 'I PUMPED 40 -BBL. SAFE - SURF -O PILL SURFACE TO SURFACE AT 10 -12 BPM @ 600 -PSI TO 750 -PSI. S/D PUMP. MONITOR • WELL - STATIC. BLEW DOWN TOP DRIVE. LAYED DOWN SINGLE JOINT OF 4" DRILLPIPE. 16:45 - 17:30 0.75 FISH P 1 DECOMP POH TO 258'. MONITOR WELL @ BHA - STATIC. 17:30 19:00 1.50 FISH j P DECOMP I CHANGE PROM 4" DP HANDLING TOOLS TO ' BHA HANDLING TOOLS. LAYED DOWN OIL I JARS AND STOOD BACK DRILL COLLARS. F LAYED DOWNWASHPIPE BI-IA. HOLE FILL i;ON TRIP OUT OF HOLE CORRECT. 1 19:00 - 20:00 1.00 FISH P DECOMP CLEAR AND CLEAN RIG FLOOR. 20:00 - 21:00 1.00 FISH P --- DECOMP MAKE UP 8-1/4" MULTISTRING CASING I CUTTER BHA. ( #10) AS FOLLOWS: 1- 8-1/2" TAPERED MILL �-XO ■ - 8 -1/4" MULTISTRING CUTTER * XO - 5" DP FLEX JOINT STOP SUB I , -XO I CHANGE TO 4" DRILLPIPE HANDLING TOOLS. 21:00 - 22:00 1.00 FISH P DECOMP I RIH TO 2472'. KELLY UP AND TAG TOP OF STUMP WITH NO-GO AT 2519'. POH TO 1 POSITION CUTTER KNIVES AT 2505'. P/U WT. ' 66K, 5/0 WT. - 70K, ROT WT. - 66K, 40 -60 RPM AND 2-4K TG. ON BOTTOM. !� 22:00 - 22:30 0.50 FISH P DECOMP ESTABLISH PARAMETERS: 4 -5.5 BPM @ 300 -600 PSI, 40 -80 RPM, 2 -5K FT.LBS TQ. Gy ECl IT IN a-5is" CASING STUB AT2505' CUT INDICATORS GOOD: PUMP PRESSURE LOSS, ROTATING WEIGHT INCREASE, TQ. ; DECREASE. S/D PUMPING. MONITOR WELL - STATIC. BLEW DOWN TOP DRIVE. 22:30 - 00:00 1.50 FISH P DECOMP POH TO 26'. MONITOR WELL - STATIC. CHANGE TO BHA HANDLING TOOLS. LAY DOWN BHA #10. HOLE FILL CORRECT ON TRIP OUT OF HOLE. 12/28/2010 00:00 - 00:30 0.50 FISH P DECOMP PJSM TOUR CREW CHANGE - DISCUSS COLD WEATHER OPERATIONS WITH CREW. NO WORK OUTSIDE PERMITTED WITHOUT FIRST 1 CONSULTING WITH WSL, TOURPUSHER AND DRILLER. AMBIENT TEMP = -45F, -75WC. RIG LOADER PARKED IN SHOP. 00:30 - 01:00 0.50 FISH P DECOMP MAKE SPEAR BHA ( #11) AS FOLLOWS: - 4 -1/2" BULL NOSE - 8 -1/4" ITCO SPEAR - SPEAR EXTENSION 1 SPEAR EXTENSIO N - STOP SUB W/10 -3/4" STOP -XO Printed 3/3/2011 2:04:45PM North America - ALASKA BP} P n13 0f 22 x peration Summary Repor t Common Well Name: NGI -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 End Date: X4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15 : 14 5/14/1979 00:00 @48.00ft (above Mean Sea Level) Date From - To Hrs Task Code ! NPT NPT Depth Phase Description of Operations (hr) (ft) 01 :00 - 02 :30 1.50 FISH P DECOMP RIH WITH SPEAR BHA ( #11) ON 4" XT -39 DRILLPIPE FROM DERRICK. TAG TOP OF 9 -5/8" CASING FISH AT 2496'. ENGAGE FISH WITH SPEAR. SET DOWN 15K. 02:30 04:00 1.50 FISH DECOMP POH WITH BHA #11 AND FISH. 04:00 - 05:00 1.00 FISH P DECOMP °f LAY DOWN BHA #11 AND 9 -5/8" CASING FISH. • [FISH LENGTH = 10.26 FT. PHOTOS OF FISH E- MAILED TO RWO ENGINEER. -_ 1 05:00 - 06:00 1.00 FISH P DECOMP "MOVE DRESS -OFF MILL TO RIG FLOOR. I MAKE UP DRESS -OFF BHA ( #12). 06:00 - 08:00 2.00 FISH P DECOMP RUN IN THE HOLE TO 2456'. TAG UP ON 9 -5/8" AT 2505'. - UP WT. 75K / DOWN WT. 81K / ROT WT. 75K 08:00 - 11:15 1 3.25 FISH P DECOMP POLISH OFF THE STUB FROM 2505' TO 2506' AT 6 BPM WITH 200 PSt AT 80 RPM AND 1-4K TQ. 1 11:15 - 12:00 0.75 FISH P j DECOMP 1 CIRCULATE A BOTTOMS UP AT 12 BPM WITH I I 700 PSI. MONITOR THE WELL STATIC. 9.8 1 PPG BRINE IN AND OUT. 12:00 - 12:15 0.25 FISH P DECOMP 1BLOVV O L N THE TOP DRIVE MONITOR THE WELL 12:15 - 13:30 1.25 FISH P DECOMP PULL OUT OF THE HOLE TO 201'. MONITOR - . THE WELL STATIC. CHANGE OUT THE HANDLING EQUIPMENT, RACK BACK THE COLLARS AND LAY DOWN THE POLISH MILL ASSEMBLY. SAW GOOD INDICATIONS ON THE MILL OF EVEN DRESS OFF. 13:30 - 15:15 1.75 BOPSUR i '- P DECOMP I CHANGE OUT THE TOP RAMS FROM 7" CASING RAMS TO 7 -5/8" CASING RAMS. _ 15:15 - 17:00 1.75 BOPSUR P DECOMP RIG UP TO TEST THE BOPE. 17.00 22:30 5.50 BOPSUR P DECOMP 'FRIG _ULD TEST EQUIPMENT. TEST BOPE PER BP /AOGCC REQUIREMENTS TO 250 -PSI LO /4000 -PSI HI AND 5 CHARTED MINUTES EACH PRESSURE. TESTED PIPE RAMS WITH 4" AND 7 -5/8" TEST JOINTS. TESTED ANNULAR PREVENTER WITH 4" AND 7 -5/8" 4/ v ' TEST JOINTS TO 3500 PSI. PERFORMED / ACCUMULATOR TEST. TEST WITNESSED BY ( ' 0 5 BP WSL MIKE DINGER AND CHRIS KOBUCK, DOYON PUSHERS PAT KRUPA AND JOHN PIPER. AOGCC REP CHUCK SCHEVE WITNESSED THE BOP TEST. 00:00 1.50 22:30 - BOPSUR 11 P DECOMP RIG DOWN TEST EQUIPMENT, BLOW DOWN i THE CHOKE MANIFOLD AND KILL LINES. 12/29/2010 1 00:00 - 06:00 6.00 FISH N DPRB DECOMP WAIT ON WEATHER DUE TO CURRENT TEMPERATURE OF -44 AND WINDCHILL OF -72. LOADER OPERATIONS HAVE BEEN STOPPED, THEREFORE CANNOT UNLOAD 9 -5/8" OUT OF THE SHED AND LOAD AND TRANSPORT NEW 9 -5/8" TO LOCATION. CURRENTLY HAVING ISSUES REMOVING THE TEST PLUG FROM THE WELLHEAD, CLEANING THE RIG, WHILE WORKING ON REMOVING THE TEST PLUG. Printed 3/3/2011 2:04:45PM E! tth AtYterita -ALASKA- BP e O peration Summary Report - ,/ii, ' ' y , Common Well Name: NGI -14 I AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 End Date: IX4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) I Site: NGI Rig Name /No.: DOYON 141 j Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15:14 5/14/1979 00:00 ©48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ! (ft) 06:00 - 09:00 3.00 FISH N DPRB DECOMP ATTEMPT TO REMOVE THE TEST PLUG. MAKE UP 4" JOINT OF DRILL PIPE, PULL 25K INCREMENTS UP TO 175K. MADE SEVERAL ATTEMPTS WITH NO CHANGE CONSULT WITH RWO SUPERINTENDENT GREG SARBER, OK WAS GIVEN TO APPLY PRESSURE FROM BELOW WHILE PULLING 25K INCREMENTS UP TO 140K. HAD ANNULAR CLOSED WITH PRESSURE BLED OFF WHEN PRESSURE WAS APPLIED BELOW THE TEST PLUG. NO CHANGE, DECISION I WAS MADE TO RIG DOWN EQUIPMENT. 09:00 - 12:00 I 3.00 BOPSUR j N DPRB DECOMP NIPPLE DOWN BOP STACK, SPACER SPOOL, I AND TUBING SPOOL. WHEN TUBING SPOOL WAS NIPPLED DOWN IT WAS DISCOVERED THAT THE MCEVOY TEST PLUG WAS RUN INTO A VETCO TUBING HEAD WHILE TESTING THE BOP STACK TO 4000 PSI TO ! PLUG HELD, BUT WAS COMPRESSED INTO —'i THE WELLHEAD. 12:00 - 14:30 2.50 WHSUR N DPRB DECOMP NIPPLE UP NEW TUBING SPOOL AND BOP ;STACK. _ 14:30 - 19 :45 5.25 WHSUR N DPRB ' DECOMP CLEAN AND CLEAR THE RIG FLOOR OF ALL EXCESS TOOLS. SERVICE THE TOP DRIVE, DRAW WORKS, AND IRON ROUGHNECK. I INSTALL RISER AND RIG UP TO TEST THE - I BREAKS IN THE BOP STACK. / 19:45 - 20 :30 0.75 BOPSUR N DPRB 1 DECOMP TEST THE TUBING FLANGE BREAKS TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 MINUTES EACH. CHARTED. GOOD TEST. 20:30 - 00:00 3.50 FISH N WAIT DECOMP WAIT ON WEATHER DUE TO TEMPERATURES AROUND -42. SIM OPS. CHANGE OUT DEMCO VALVES IN ROCKWASHERAND RABBIT 7 -5/8" TUBING. - MORGANS CREW HELD EVACUATION DRILL CRT 165 SEC. 12/30/2010 00:00 - 13:00 13.00 FISH N WAIT DECOMP WAITING ON WEATHER TO WARM UP TO RESUME NORMAL OPERATIONS. CHANGE OUT PUMP IN THE TRIP TANK, CLEAN THROUGHOUT THE RIG. PERFORM DOYON MP2 MAINTENANCE PROGRAM, AND SERVICE THE TOP DRIVE REPAIR THE VALVE IN THE RIG VAC SYSTEM AND RIG I FLOOR STEAM HEATER. 13:00 21:30 8.50 CASING P DECOMP ! OFFLOAD USED 9 -5/8" CASING OUT OF THE PIPE SHED, LOAD NEW 9-5/8" CASING, ECP, AND ES CEMENTER INTO THE PIPE SHED. DRIFT AND STRAP 9 -5/8" CASING. MAKE UP TIW AND SAFETY JOINT TO PROPER CROSSOVER. RIG UP CASING EQUIPMENT. Printed 3/3/2011 2:04:45PM North America- A .ASKA BR Page - i5 tali peratQra Summary Report Common Well Name: NGI -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 End Date: X4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15:14 5/14/1979 00:00 ©48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:30 - 00:00 2.50 CASING P DECOMP MAKE UP 9 -5/8" CASING AS FOLLOWS: 1- 95/8" BAKER ( BOWEN) CASING PATCH (BTC BOX) '- 9 -5/8" 47# L -80 BTC HANDLING PUP (BTC 130X X PIN) - 9-5/8" BAKER ISO -ZONE EXTERNAL CASING PACKER - 9 -5/8 ", 47# L -80 BTC HANDLING PUP (BTC BOX X PIN) - 9 -5/8" 47# L -80 BTC HANDLING PUP (BTC BOX X PIN), 9- 5 /8 "HES ES CEMENTER - 9 -5/8" 47# L -80 X -O HANDLING PUP (HYDRIL BOX X BTC PIN) <' - 16 JTS ( #1 - # 1 9 5/8" , 47# L -80 HYD 563 CASING ALL CONNECTIONS BELOW ES CEMENTER WERE BAKERLOK'D. ALL JOINTS TORQUED TO OPT. OF 15 FT /LBS AND UTILIZING JET LUBE SEAL GUARD. 12/31/2010 00:00 - 04:30 4.50 CASING P D - EC OMP, 'CONTINUE TO MAKE UP 9 -5/8" CASING AS 1 FOLLOWS: l 43 JTS ( #17 - #58) 9 5/8" 47# L -80 HYD 563 1 1 CASING - 1 PUP JT. 9 5/8" 47# L -80 HYD 563 CASING 14.83' - 1 JTS 9 5/8" 47# L -80 HYD 563 CASING ALL JOINTS TORQUED TO OPT. OF 15,800 FT /LBS AND UTILIZING JET LUBE SEAL GUARD. 04:30 - 05 :00 0.50 CASING P DECOMP SET BOWEN CASING PATCH GRAPPLE. SET DOWN 20K, PULL 30K OVER TO SET THE GRAPPLE. PULL TEST TO 250K. SLACK OFF TO 135K, SET THE SLIPS. MAKE UP THE CEMENT HEAD AND CROSSOVERS. 05:00 - 05:30 0.50 CASING P DECOMP RIG DOWN CASING EQUIPMENT AND CLEAR THE FLOOR. 05:30 - 06:00 j 0.50 CASING P r DECOMP CHANGE OUT THE BAILS AND ELEVATORS. 06:00 - 07:00 1.00 CASING P DECOMP PULL UP TO 225K, PRESSURE UP TO 1000 PSI AND CHART FOR 10 MINUTES. GOOD TEST. INCREASE PRESSURE TO 1600 PSI AND INFLATE THE ECP. OBSERVE PRESSURE DROP TO 1500 PSI, PRESSURE UP TO 2000 PSI AND TEST FOR 10 MINUTES CHARTED. GOOD TEST. BLEED OFF PRESSURE AND PRESSURE UP TO 2750 PSI TO OPEN THE ES CEMENTER. POSITIVE INDICATION OF CEMENTER OPENING AND OBSERVED RETURNS AT SURFACE. 07:00 - 08:00 j 1.00 CASING P DECOMP CIRCULATE HEATED 9.8 PPG BRINE AT 7.5 BPM WITH 300 PSI UNTIL RETURNS WERE AT 80 DEGREES FOR THE CEMENT JOB. Printed 3/3/2011 2:04:45PM firth America - ALASKA - BP Pa 16 of 22 Aeration Summary Report il im , j Common Well Name: NGI -14 I AFE No Event Type: WORKOVER (WO) ' Start Date: 12/10/2010 End Date: F X4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 1 Spud Date/Time: I Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15 : 14 5/14/1979 00:00 @48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth i Phase i Description of Operations (hr) (ft) 08:00 - 10:00 2.00 CASING P DECOMP 1PUMP 5 BBLS OF WATER, PRESSURE TEST ALL LINES TO 4000 PSI. GOOD TEST. PUMP %b 168 BBLS (831 SX) OF 15.8 PPG CLASS G _ A1 D CEMENT (1.17 CU. FT YIELD) DROP THE PLUG IAND KICK OUT WITH 5 BBLS OF WATER. ,_„7� DISPLACE WITH THE RIG PUMPS AT 5 BPM U'"_ WITH ICP OF 200 PSI. CAUGHT CEMENT AND PRESSURE GRADUALLY INCREASED FROM 200 PSI TO 600 PSI. AT 1000 STKS DISPLACED CLOSED THE BAG TO DIVERT f RETURNS TO THE ROCKWASHER TO ENSURE NO CEMENT GOT INTO THE BOP STACK. SLOWED PUMPS TO 2 BPM WITH 800 PSI AT 1750 STKS { DISPLACED. SLOWED TO 1 BPM AT 1900 STKS DISPLACED AND BUMPED PLUG AT 1200 PSI WITH 2058 STKS. PRESSURED UP TO CLOSE THE ES I CEMENTER AT 1900 PSI,CONTINUED PRESSURE TO 2200 PSI. HELD FOR 10 I � i MINUTES. BLED OFF TO CHECK FOR FLOW. FLOATS HELD. CIP 10:00 10:00 - 11:00 1.00 CASING P DECOMP FLUSHED OUT THE STACK WITH WATER AND I SUCKED OUT THE OA PORTS. RIGGED DOWN THE CEMENT HEAD. WELL STATIC. 11:00 - 12:15 1.25 WHSUR P DECOMP NIPPLE DOWN THE BOP STACK AND TUBING 1 I SPOOL. 12:15 - 13:30 1.25 WHSUR P DECOMP §ET EMERGENCY SLIPS AND CUT THE 9 -5/8" _ _ ; CASING. 13:30 - 15:30 2.00 WHSUR P DECOMP I INSTALL PRIMARY AND SECONDARY I PACK -OFF IN BOTTOM OF TUBING SPOOL. SIM OPS: RIG DOWN CASING EQUIPMENT. 15:30 - 17:30 2.00 WHSUR P ! DECOMP NIPPLE UP TUBING SPOOL AND BOP STACK. TEST PACK OFF TO 3800 PSI FOR 30 MINUTES. GOOD TEST. 17:30 - 18:30 1.00 CLEAN P DECOMP PICK BAKER FISHING TOOLS UP THE BEAVER SLIDE. RIG UP TO PRESSURE TEST _ BREAKS MADE IN BOP STACK. 18:30 - 23:00 4.50 BOPSUR N DPRB DECOMP ' SET TEST PLUG AND ATTEMPT TO PRESSURE TEST THE BREAKS IN THE BOP STACK. TEST PLUG NOT GAINING A PROPER I SEAL. PULLED THE TEST PLUG OUT AND DISCOVERED A SMALL GROOVE CUT INTO THE SEALING SURFACE. CALLED OUT CAMERON TO DELIVER A NEW PLUG. 23:00 - 00:00 '� 1.00 BOPSUR P DECOMP SET N.EW TEST PLUG AND TESTED THE I BREAKS IN THE BOP STACK TO 250 PSI LOW / 4000 PSI HIGH FOR 5 CHARTED MINUTES. GOOD TEST. 1/1/2011 00:00 - 02:45 2.75 CLEAN P DECOMP I MAKE UP CEMENT CLEANOUT BHA AS FOLLOWS: - 8.5" HYCALOG BIT - (4) 7" BOOT BASKETS - BIT SUB - 6.25" BOWEN LUB BUMPER SUB i - 6.25" BOWEN OIL JAR - PUMP OUT SUB I k- 6.75" SPIRAL DRILL COLLARS - XO SUB 1 1 I -XO SUB Printed 3/3/2011 2:04:45PM a rth Amestca ALASKA - a 17 iif 22 p rat i ©rr Summary a ryl R Common Well Name: NGI -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 ; End Date: X4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15 14 5/14/1979 00:00 @48.00ft (above Mean Sea Level) Date 1 From - To Firs Task Code I NPT ; NPT Depth Phase 1 Description of Operations (hr) (ft) 02:45 - 04:00 1.25 CLEAN P DECOMP RUN IN THE HOLE ON 4" DRILL PIPE TO 2415'. I WASH DOWN AT 3 BPM AND SEE CEMENT STRINGER AT 2432'. PICK UP AND ESTABLISH PARAMETERS. UP WT. 85K / DOWN WT. 70K / ROT WT. 77K AT 60 RPM WITH 1 -2K TQ. CIRCULATE AT 8 BPM WITH 400 PSI. 04:00 - 08:00 4.00 CLEAN P DECOMP DRILL UP CEMENT AT 8 BPM WITH 400 PSI. WOB 2 -3K , UP WT. 85K / DOWN WT. 70K / ROT WT. 77K AT 60 RPM WITH 1 -2K TQ. 'DRILL UP THE STRINGER AT 2434', ROTATE 1 DOWN TO 2462' AND TAG GOOD CEMENT. DRILL CEMENT AT 7 BPM WITH 450 PSI WITH 1 -2K TQ, 2 -3K WOB, AND 100 RPM FROM 2462' _ -25`. ' 46 08:00 - 09:00 1.00 CLEAN P DECOMP WASH DOWN TO FIND THE TOP OF SAND @ 2542' AT 1.5 BPM. 1 09:00 - 09:30 0.50 CLEAN P DECOMP WASH FROM 2542' TO 2545' AT 1.5 BPM. 09:30 - 10:00 0.50 CLEAN P DECOMP !PUMP 20 BBL HI-VIS SWEEP AT 500 PSI WITH i 8.5 BPM. 10:00 - 10:30 0.50 CLEAN P DECOMP I FLOW CHECK THE WELL. STATIC. BLOW I DOWN THE TOP DRIVE AND PREPARE TO I PULL OUT OF THE HOLE. 10:30 - 12:30 2.00 CLEAN P DECOMP l PULL OUT OF THE HOLE RACKING BACK THE DRILL PIPE AND DRILL COLLARS. 12:30 - 13:00 0.50. `l CLEAN P DECOMP BREAK OFF THE BIT AND JUNK BASKETS. JUNK BASKETS HAD 3 GALLONS OF SAND AND CEMENT DEBRIS. 13:00 - 14:30 1.50 CLEAN P 1 DECOMP MAKE UP RCJB CLEANOUT BHA AS FOLLOWS: I- 7.875" RCJB WITH 8.5" HEAD - (4) 7" BOOT BASKETS i - 9.625" CASING SCRAPER -BIT SUB - 6.25" BOWEN LUB BUMPER SUB - 6.25" BOWEN OIL JAR - PUMP OUT SUB - 6.75" SPIRAL DRILL COLLARS - XO SUB 1 XO SUB 14:30 - 16:30 2.00 CLEAN P DECOMP , RUN IN THE HOLE ON 4" DRILL PIPE AND TAG SAND AT 2545'. PICK UP AND CIRCULATE AT 8 BPM WITH 1050 PSI. UP WT. 80K / DOWN 1 WT. 82K 16:30 - 18:00 1.50 CLEAN P DECOMP 1 DROP RCJB BALL AND PUMP DOWN AT 4 BPM WITH 300 PSI. PRESSSURE INCEASE 11 TO 500 PSI WHEN BALL WENT ON SEAT. STAGED UP THE PUMPS TO 6 BPM WITH 2400 PSI, ROTATING AT 60 RPM AND WASH DOWN TO 2560'. RECIPROCATE WHILE CIRCULATING 1.5 BOTTOMS UP AT 6 BPM WITH 2400 PSI. 18 :00 - 20:00 2.00 CLEAN P DECOMP I PULL OUT OF THE HOLE AND LAYDOWN RCJB AND BOOT BASKETS. REMOVE SCRAPER FROM THE STRING. RCJB HAD (5) 2" X 5" PIECES OFF OF THE 9 -5/8" BOW SPRING CENTRALIZER. - SHUMWAY'S CREW HELD KICK WHILE TRIPPING DRILL, CRT 95 SEC. Printed 3/3/2011 2:04:45PM North America - _ ALASKA B i 2a, ration Summary Report Common Well Name: NGI -14 1 AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 End Date: X4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15 : 14 5/14/1979 00:00 ©48.00ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT ' NPT Depth Phase ; Description of Operations (hr) 1 (ft) 20:00 - 21:15 1.25 CLEAN I P DECOMP MAKE UP RCJB CLEANOUT BHA AS FOLLOWS: i - 7.875" RCJB WITH 8.5" HEAD j - (4) 7" BOOT BASKETS 1- BIT SUB i - 6.25" BOWEN LUB BUMPER SUB - 6.25" BOWEN OIL JAR i'- PUMP OUT SUB I- 6.75" SPIRAL DRILL COLLARS I I- XO SUB I XO SUB 21:15 - 00:00 2.75 CLEAN P i DECOMP RUN IN THE HOLE ON 4" DRILL PIPE AND TAG _ i SAND AT 2560'. ESTABLISH CIRCULATION AT 6 BPM WTIH 700 PSI, DROP THE BALL AND SEE PRESSURE INCREASE TO 2400 PSI. _ T BOTTOMS P TO 2580' AND CIRCULATION 1/2/2011 ! 00:00 - 00:15 j 0.25 CLEAN P DECOMP MONITOR THE WELL. STATIC. BLOW DOWN THE TOP DRIVE. 100:15 - 01:30 1.25 j CLEAN P 1 DECOMP PULL OUT OF THE HOLE FROM 2580' TO 263'. 01:30 - 03:00 1.50 CLEAN P ; DECOMP, LAY DOWN THE BHA AND BREAK DOWN THE RCJB. RETRIEVED ONE 5 "X 2" PIECE OUT OF , ' THE RCJB. 03:00 - 03:30 0.50 CLEAN P DECOMP CLEAN AND CLEAR THE RIG FLOOR. / 03:30 - 04 :15 0.75 CLEAN P DECOMP � PRESSURE TEST THE 9 -5/8" CASING TO4QQQ_. PSI FOR 30 MINUTES. GOOD TEST. 04:15 - 05:00 0.75 CLEAN- P DECOMP SERVICE THE TOP DRIVE, DRAW WORKS AND IRON ROUGHNECK. 05:00 - 06:00 1.00 1 CLEAN P DECOMP PICK UP RBP RETRIEVAL TOOL AND RUN IN THE HOLE ON 4" DRILL PIPE TO 2520'. 06:00 - 06:30 0.50 CLEAN P DECOMP WASH DOWN TO 2585' AND ENGAGE THE PLUG. 06:30 - 07:00 1 0.50 CLEAN P DECOMP PUMP A 30 BBL SWEEP AT 12 BPM WITH 800 PSI. 07:00 07:30 0.50 CLEAN P DECOMP 1PULL 10K OVER TO CONFIRM PLUG IS ENGAGED. HOLD PJSM WITH CREW ABOUT WELL CONTROL. 1 07:30 - 08:00 0.50 CLEAN P DECOMP I PULL 10K OVER, TURN 1/2 TURN TO THE I j ;RIGHT TO OPEN THE BYPASS PORT. MONITOR THE WELL FOR 10 MINUTES. STATIC. PICK UP TO 30K OVER AND 08.00 08:30 L — RELEASE THE PLUG. LEAS 0.50 CLEAN P DECOMP 1MONITOR THE WELL AND BLOW DOWN THE PUP DRIVE. 1- 08:30 - 10:30 2.00 CLEAN P DECOMP ' .. PULL OUT OF THE HOLE AND LAY DOWN THE RBP. 10:30 DECOMP 11:00 0.50 CLEAN I P j I CLEAN RIG FLOOR OF ALL UN- NECESSARY TOOLS AND EQUIPMENT. 11 :00 13:30 2.50 BOPSUR P ' DECOMP I CHANGE THE TOP RAMS FROM 7 -5/8" FIXED i 1T03- 1 /2 "X6 "VBR'S. (J 13:30 - 15:00 1.50 BOPSUR P ' DECOMP1 RIG UP AND TEST THE TOP RAMS TO 250 PSI LOW/ 4000 PSI HIGH FOR 5 MINUTES EACH. I GOOD TEST. 15:00 - 15:30 I l r 0.50 I WHSUR P DECOMP LAY DOWN THE TEST EQUIPMENT AND 1_ INSTALL THE WEAR BUSHING. Printed 3/3/2011 2:04:45PM NQP� [ @ETC3 ` A S B pais. 19 022 peration Summary Report Common Well Name: NGI -14 AFE No _ a Event Type: WORKOVER (WO) Start Date: 12/10/2010 End Date: X4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 Spud Date/Time: 1 Rig Release: Rig Contractor: DOYON DRILLING INC. 1 UWI: Active Datum: 15:14 5/14/1979 00:00 @48.00ft (above Mean Sea Level) Date From - To Hrs [ Task Code NPT NPT Depth Phase Description of Operations (hr) 15:30 - 17:30 2.00 CLEAN P DECOMP PICK UP CASING SCRAPER BHA AS FOLLOWS: - BULL NOSE 1 - DRILL PIPE PUP - XO PIN X PIN � I -' ".6 " A IN CRAPER - BIT SUB 6.25" BOWEN LUB BUMPER SUB - 6.25" BOWEN OIL JAR PUMP OUT SUB 1- 6.75" SPIRAL. DRILL COLLARS XO SUB 17:30 - 20:30 3.00 CLEAN 1 P DECOMP , RUN IN THE HOLE TO 7939'. RECIPROCATE I AND ROTATE A FULL STAND FOUR TIMES. CONTINUE IN THE HOLE TO 8033'. UP WT. 150K / DOWN"WT. 130K 20:30 - 22:00 1.50 CLEAN P 1 DECOMP 1 CIRCULATE AT 4 BPM WITH 250 PSI. WASH 4 C J DOWN'TO "8100' AND TAG THE TIE BACK RECEPTACLE AT 8084'. SAW PRESSURE INCREASE TO 350 PSI. PUMP 30 BBL SPACER FOLLWED BY HEATED 9.8 PPG BRINE AT 8 BPM WITH 800 PSI. PUMPED A TOTAL OF 620 BBLS. 22:00 - 22:30 E 0.50 CLEAN P : DECOMP "MONITOR THE WELL. RIG UP TO PULL OUT OF THE HOLE ON ELEVATORS. 22:30 - 00:00 1.50 CLEAN P DECOMP PULL OUT OF THE HOLE LAYING DOWN 4" j [ DRILL PIPE TO 7100'. SHUMWAY CREW: FIRE DRILL, CRT 45 SEC. 1/3/2011 00:00 - 05:30 5.50 CLEAN P DECOMP ! PULL OUT OF THE HOLE FROM 7100' LAYING DOWN THE DRILL PIPE. - KRUGER'S CREW: KICK WHILE TRIPPING 1 DRILL, CRT 63 SEC. 05:30 - 07:00 1.50 CLEAN P DECOMP LAY DOWN THE SPIRAL DRILL COLLARS AND SCRAPER BHA. 07:00 - 08:00 1.00 CLEAN P l DECOMP CLEAN AND CLEAR THE RIG FLOOR. PULL THE WEAR BUSHING. A g 08:00 - 09:45 1.75 BOPSUR P ! DECOMP RUN AND SET THE TEST PLU>; CHAN(;F , OUT THE TOP RAMS TO 7 -5/8" FIXED CASING W D RAMS. 09:45 11:15 1.50 BOPSUR P DECOMP TEST THE 7 -5/8" FIXED CASING RAMS TO 250 PSI LOW / 4000 PSI HIGH FOR 5 MINUTES CHARTED. GOOD TEST. RIG DOWN TESTING EQUIPMENT. 11:15 - 12:30 j 1.25 RUNCOM P RUNCMP !RIG UP CASING EQUIPMENT AND j CROSSOVER TO TIW VALVE. 12:30 14:00 1.50 RUNCOM P RUNCMP 1 MAKE DUMMY RUN WITH THE TUBING HANGER. Printed 3/3/2011 2:04:45PM orttt America - ALASKA - BP Psi', 2O c 2 2 Aeration, Summary Report Common Well Name: NGI -14 AFE No Event X4 -OORXG (3,205,000.00 nT WORKOVER e t e: WORKO ER WO Start Date: 12/10/2010 ' Type: ( ) End Date: Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 I Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. l UWI: Active Datum: 15:14 5/14/1979 00:00 ©48.00ft (above Mean Sea Level) Date ' From - To Hrs Task Code ; NPT ! NPT Depth Phase Description of Operations (hr) (ft) ,14:00 - 15:30 1.50 RUNCOM P RUNCMP MAKE UP 7 -5/8" COMPLETION AS FOLLOWS* - 7" 26# L -80 TC-II WLEG - 7" 26# L -80 TC-II PUP - 7" "RN" NIPPLE 5.770 "ID W/ RHC -M SLEEVE 7" 26# L -80 TC-II PUP 1 JT. 7" 26# L -80 TC-II - 7" 26# L -80 TC-II PUP 1- 7" "R" NIPPLE 5.963" ID TC-II - 7 "26#`L- 80TC -II PUP fr - BAKER .9.5 /8 "X 7" S -3 PERMANENT PACKER 1- 7" 26 #,L- 80'TC-II PUP I -`7 26 #L- 80TC -II PUP -7 "R" NIPPLE 5.963" ID TC-II -7" 26# L -80 T PUP - 1 JT. 7" 26# L -80 TG11 ` - 7 5/8" 29,7# VAM TOP BOX X 7" 26# L -80 TC-II PIN - (3) 7 -5/& 29.7# VAM TOP HC IPC #1 TO #3 ALL CONNECTIONS BELOW THE PACKER WERE BAKERLOK'D. UTILIZED JET LUBE ' SEAL GUARD ON ALL OTHER CONNECTIONS. F7" TC-II CONNECTIONS WERE TORQUE TURNED TO 10,100 FT /LBS. AND 7 -5/8" VAM TOP CONNECTIONS WERE TORQUE TURNED TO 14,450 FT /LBS. 15:30 - 17:30 2.00 RUNCOM N SFAL 230.00 RUNCMP CASING TONGS FAILED, TROUBLE SHOOT HYDRAULICS. CHANGE OUT CASING TONGS TO A NEW SET. 17:30 - 00:00 6.50 RUNCOM P RUNCMP I CONTINUED TO MAKE UP COMPLETION AS FOLLOWS: '- 91 JTS. 7 -5/8" 29.7# VAM TOP HC IPC #3 TO #93 UTILIZED JET LUBE SEAL GUARD ON ALL CONNECTIONS. 7 -5/8" VAM TOP CONNECTIONS WERE TORQUE TURNED TO 14,450 FT /LBS. 1/4/2011 00:00 - 06:00 6.00 RUNCOM P RUNCMP CONTINUE TO RUN 7 -5/8" COMPLETION AS FOLLOWS: - 43 JTS. 7 -5/8" 29.7# VAM TOP HC IPC #94 TO 1 #136 - 7 -5/8" 29.7# VAM TOP HC PUP I I � - 7" TC-II BOX X 7 -5/8" 29.7# L -80 VAM TOP HC PIN - 7" "DB-6" NIPPLE 6.00" ID TC-II - 7 -5/8" 29.7# VAM TOP BOX X 7" 26# L -80 TC-II PIN - 7 -5/8" 29.7# VAM TOP HC PUP - 52 JTS. 7 -5/8" 29.7# VAM TOP HC IPC #137 TO #188 - HANGER PUP JT. TC-II BOX X 7 -5/8" VAM 'TOP HC PIN - MCEVOY SSH HANGER MS/CCL 13" X 7" TC-II !TOP AND BOTTOM UTILIZED JET LUBE SEAL GUARD ON ALL CONNECTIONS. 7 -5/8" VAM TOP CONNECTIONS WERE TORQUE TURNED TO 14,450 FT /LBS. r RUNCMP l IN THE LOCKDOWN SCREWS. 06:00 06:30 0.50 RUNCOM P `_ Printed 3/3/2011 2:04:45PM North America - ALASKA BP 24 o 22 s pera S ummary Rep Common Well Name: NGI -14 ! AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 End Date: X4 -00RXG (3,205,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 Spud Date/Time: I Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 15:14 5/14/1979 00:00 @48.00ft (above Mean Sea Level) Date From - To Firs Task Code NPT 1 NPT Depth Phase Description of Operations (hr) I (ft) 06:30 - 09:30 3.00 RUNCOM P RUNCMP REVERSE CIRCULATE 375 BBLS OF 120 DEGREE 9.8 PPG BRINE FOLLOWED BY 100 BBLS OF CORROSION INHIBITED BRINE AT 3 BPM WITH 350 PSI. 1 09:30 - 11:00 1.50 WHSUR ! P WHDTRE RIG UP LRS AND PRESSURE TEST LINES TO 3500 PSI. PUMP 40 BBLS OF DIESEL AND MALLOW TO U -TUBE. 11:00 - 12:00 1.00 WHSUR P WHDTRE TALLOW WELL TO U -TUBE. PICK UP DUTCH ' RISER SYSTEM TO THE RIG FLOOR. , "MONITOR THE WELL STATIC. 12:00 - 14:00 2.00 RUNCOM P RUNCMP INSTALL THE LANDING JOINT AND DROP THE ;BALL AND ROD WITH A 1 -7/8" BALL. LAY ', DOWN THE LANDING JOINT, CLOSE THE I BLIND RAMS TO SET THE BALL AND ROD ON SEAT AND TFST THE TUBING TO 4000 PSI iFOR 30 MINUTES. GOOD TEST. BLEED OFF j ik THE PRESSURE TO 1500 PSI INTHHE TUBING AND PRESSURE UP THE ANNULUS TO 4000 PSI. SEE ThE PACKER BEGIN SETTING AT ' 2000 PSI. TEST FOR 30 MINUTES. GOOD TEST. AOGCC REP BOB NOBLE WAIVED ■ WITNESS OF PRESSURE TESTS ON [INJECTOR WELL. 14:00 - 16:30 2.50 WHSUR P WHDTRE I PICK UP LUBRICATOR AND TEST TO 250 PSI LOW AND 1000 PSI HIGH FOR 5 MINUTES. SET THE TWC AND RIG DOWN THE LUBRICATOR. 16:30 - 18:30 2.00 WHSUR- P . WHDTRE CLOSE THE BLINDS AND TEST THE TWC TO 1250 PSI LOW / 4000 PSI HIGH FOR 5 MINUTES EACH CHARTED. GOOD TEST. 18:30 - 21:30 3.00 WHSUR P WHDTRE I FLUSH MUD PUMPS, KILL LINE, AND BOP STACK WITH FRESH WATER. CLEAN AND CLEAR THE RIG FLOOR AND DRIP PAN. 21:30 - 00:00 2.50 WHSUR P WHDTRE NIPPLE DOWN THE DUTCH RISER SYSTEM AND CHANGE OUT THE TOP RAMS FROM 7 -5/8" TO 3 -1/2" X 6" VBR'S. 1/5/2011 00:00 - 01:00 1.00 WHSUR P WHDTRE NIPPLE DOWN THE BOP STACK AND STAND BACK ON THE STUMP. 01:00 - 02:00 1.00 WHSUR P WHDTRE CAMERON PREPARE THE WELLHEAD TO 1 NIPPLE UP THE DRY HOLE TREE. 1 102:00 - 04:00 2.00 WHSUR l P WHDTRE NIPPLE UP ADAPTOR FLANGE AND THE DRY HOLE TREE CONSISTING OF TWO 7 1/6" 5000# VALVES AND A TREE CAP. INSTALL DOUBLE 2 1/16" VALVES ON ONE SIDE OF IA SAND VR PLUG ON THE OTHER SIDE. INSTALL DOUBLE 3 1/8" VALVES ON ONE SIDE OF OA 'AND VR PLUG ON THE OTHER SIDE. 1 04:00 - 05:30 1 .50 WHSUR Ii P WHDTRE TEST THE TUBING HANGER VOID AND SEALS TO 5000 PSI FOR 30 MINUTES. GOOD 1 I I TEST. TEST ADAPTOR SPOOL TO 5000 PSI. I 1 GOOD TEST. 05:30 - 07:30 2.00 WHSUR P WHDTRE TEST THE DRY HOLE TREE TO 250 PSI LOW 07.30 08:30 1.00 WHSUR P WHDTRE AND 5000 PSI HIGH. GOOD TEST. RIG UP DSM HYDRAULIC LUBRICATOR AND 1 TEST TO 300 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES. 08:30 - 10:30 2.00 WHSUR P [ WHDTRE REMOVE TWC. PICKUP BPV, MAKE UP LUBRICATOR. TEST LUBRICATOR TO 300 PSI L 1 LOW AND 3500 PSI HIGH. INSTALL BPV. Printed 3/3/2011 2:04:45PM Report orth.Ame - -AIASi BP" F cf ? JJ ir; d r y,/ p � , , „ - rrt�mat�r` Common Well Name: NGI -14 AFE No Event Type: WORKOVER (WO) Start Date: 12/10/2010 End Date: IX4 -00RXG (3,205,000.00 ) 1 I 11 Project: Prudhoe Bay (various) Site: NGI Rig Name /No.: DOYON 141 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. ! UWI: Active Datum: 15:14 5/14/1979 00:00 @48.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 12:00 ( 1.50 WHSUR P WHDTRE RIG DOWN DSM HYDRAULIC LUBRICATOR AND LAY DOWN. SECURE WELL. INSTALL FLANGES, NEEDLE VALVES ADN PRESSURE GUAGES. RELEASE RIG AT 12:00 NOON JANUARY 5, 2011. RIG WAITING ON TRANSPORT TO CONOCO PHILLIPS FIELD. TRUCKS OCCUPIED WITH OTHER RIG MOVE. Printed 3/3/2011 2:04:45PM 01/20/11 Schimberg.? NO. 5676 Alaska Data & Consulting Services Company: State of Alaska 2525 GambelIStreet, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job • Log Description Date BL Color CD 14-43 BGZ7-00010 CROSSFLOVV CHECK '' ' — /1 ... 11/13/10 1 _• - • 1 1) 01-30 L-205 NGI-14 AV1H.00052 USIT fillIrl,fliiK:P BLPO-00073 MEM LDL _ 0 1,, -057 12/21/10 BL65-00012 MEM PRODUCTION PROFILE •:. O 1 i 0 /06/11 c, — 1 3 (.. BCZ2-00031 INJECTION PROFILE )=. 6J it 1111=111P.M7.571"/•11111111111 1 ,...I&W 1 A-42A rz . 12/03/10 KII., , 1 • 02-20 BBSK-00040 RST — '''' 11/19/10 ,,,, , -- ,,,I 1 07-238 AY M -00038 IMIMPITaVIIIT MIIIIIIIIIIMINININNIIIIIIII=101111111111111iiliMX' 1 K-11A BD88-00073 MCNL j(" ..- I 11103/10 _ • „, • 1 04-24 AY1M-00058 RST I ffff- q() 12/05/10 a 1 11-12 BCZ2-00033 RST ..1 , 17 6— 12/07/10 I! • 1 2-2813/0-19 BCRJ-00055 RST q O 4 A )s, 12/01/10 _ 0 1 1 • S-128 BCZ2-00035 USIT , 01/02/11 • , , • 1 1 W-220 BG4H-00025 111111111PINIMP.TAIIIMIN■111=1111•17721SEIENINI 1 S-41A 10AKA0109 OH MWD WO EDIT JralsECEMIltetalp_T4'!e97I 1 S-41AL1 10AKA01013 OH MWD/LWD EDIT ' .—. A ,... 11111311111 1 H-11 BGZ7-00014 RST / a Zr0 — 401 12119/10 1 , el , 1 — .....0 •• • , — ' ad,— PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2-1 2525 Gembell Street, Suite 400 900 E. Benson Blvd Anchorage, AK 99503-2838 ' eANNE0 CO A .„, , , • 1 - 19 • • 2 ME OT ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL ANTD GAS333 W. 7th AVENUE, SUITE 100 CONSERVATION COM USSIONT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader a -- BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU NGI-14 Sundry Number: 310-347 Dear Mr. Reem: Enclosed is the approved Ap"icatifo-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, Daniel T. Seamount, Jr. d Chair n DATED this 2,2 -day of October, 2010. Encl. STATE OF ALASKA"',10 ALASKOL AND GAS CONSERVATION COMMIAN APPLICATION FOR SUNDRY APPROVAL Io,tiv 20 AAC 25.280 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool - S Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate S Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate - S Alter Casing ® Other Gas Injection 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory - S Service ❑ Stratigraphic 178-092' 3. Address: 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20348-00-00 - 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 NGI-14 - Spacing Exception Required? ❑ Yes S No 9. Property Designation: 10. Field/ Pool(s): ADL 28302 Prudhoe Bay Field / Prudhoe Bay 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): 9515' 8515' 9469' 8474' 8160' None Casino Length Size MD TVD Burst Collapse Structural Conductor Surface 2705' 13-3/8" 2705' 2705' 4930 2670 Intermediate 7' -5/8" 8437' 7 6870 4760 Production Liner 1374' 8136' - 9510' 7298'-8511- 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 Tubing Size: Tubing Grade: Tubing MD (ft): 8988'- 94, 8044'- 8415' 7", 26# / 4-1/2", 12.6# L-80 8172' Packers and SSSV Type: 9-5/8" x 7" BKR FB -1 Packer Packers and SSSV 8096'/ 7264' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: S Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑Exploratory ❑Development ®Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 1, 2010 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged ❑ Gas S GINJ - ❑ GSTOR ❑ Abandoned 16. Verbal Approval: Date: ❑ WAG ❑ SPLUG ❑ Suspended Commission Representative: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 5645444 Printed Name avid Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 5645743 Date loo gluio Elizabeth Barker, 564-4628 Commission Use Onl Conditions of approval: N tify Commission so that a representative may witness Sundry Number. C) � 3 Cr ❑ Plug Integrity dLJ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 3 ;. Other: /-itin � Zsov psi f; T Q 2010 Subsequent Form Required: 10.q0 / Anchorage ' APPROVED BY Q ZZ 0 Approved By: COMMISSIONER THE COMMISSION Date l Form 10403 Revised 01/20ABDNIS OCT 2 2 2W5pSubmit In Duplicate `,,-) R G I NA L - `13=z I-10 • Obp G%drA"VAr NGI-14 Rig Workover is Scope of Work: Repair IA x OA communication. Pull 7" Tubing. Change casing pack -offs and tubing spool.Cut and pull 9-5/8" intermediate casing. Replace and fully cement 9-5/8" casing to surface. Install new 7-5/8" x 7" injection tubing. MASP: 2,566 psi Well Type: Gas Injector Estimated Start Date: November 1 st, 2010 Production Engineer: Bob Chivvis Intervention Engineer: Hank Baca Pre -rig prep work: S 1 Pull XXN plug at 8,160' MD. Set 4-1/2" WRP @ -8,137'. Reference tubing tally 12/6/88. Dump 10' of sluggits and set a junk catcher F 2 CMIT-IA x OA to 2,000 psi. W 3 Check the tubing and casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage check one at a time). PPPOT-T & IC. V 4 Set a BPV in the tubing hanger. Secure well. 101 5 1 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure: 1. MIRU Rig. ND tree. NU 3 Preventer BOPE with annular, blinds, mudcross and 3-1/2 x 6" VBRs. Pressure test the VBRs and blind rams to 4,000 psi, annular to 3,500 psi. 2. RIH with mechanical casing cutter on 4" drill pipe to cut 7" casing @ -8000'. POOH standing back. 3. Set test plug in wellhead. Change out the 3-'/2" x 6" VBR's to 7" fixed rams and test to 4,OOOpsi with a 7" test joint (two barriers are the packer / WRP and test plug) 4. Pull and LD 7" tubing string from cut. Change 7" fixed rams back to 3-1/2" x 6" VBRs and test. 5. Retrieve seal assembly. 6. RU E -line, Run USIT in the 95/8" casing to determine TOC in the 9-5/8" x 13-3/s" annulus. 7. Set 9-5/8" retrievable bridge plug 100' below the top of cement. . 8. Cut and Pull 9-/8" surface casing. Note: Pipe rams will not be changed to 9-%" as the well has two tested barriers (packer / WRP plug and RBP) to the reservoir. 9. Run and fully cement 9_5/8,'L-80 47# Hydril 563 casing with ECP, ES Cementer and casing patch to surface. 10. Drill out shoe tract and retrieve the RBP. 11. Run a scraper, circulate the well to clean 9.8ppg NaCl and retrieve the junk catcher. Set a test plug. 12. Change out the 3-'/2" x 6" VBR's to 7-5/8" fixed rams and test to 4,000 psi with a 7-5/8" test joint (two barriers are the packer / WRP and test plug) 13. Run 7-5/8" 29.7# L-80 VamTopHC IPC injection completion to SSSV @ -2200'. 14. Hang off the 7-5/8" on a test plug and change the 7-5/8" fixed rams to 7" fixed and test to 4,000 psi with a 7" test joint (two barriers are the packer / WRP and test plug). 15. Run the 7" completion with control lines to surface. NOTE: control line will not fit with 7-5/8". 16. Displace the IA to completion fluid, freeze protect and set the packer. 17. Test tubing and IA to 4,000 psi. 0 18. Set TWC. ND BOPE. NU and test tree. RDMO. Post rig work• i S 1 Pull HRG sleeve, ball -n -rod, RHC seat, bail sluggits, pull WRP, install SCSSSV. F 12 1 MIT -IA post put on injection-AOGCC TREE = - WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 48' BF. R EV 8988-9280 KOP _ 3400' Max Angle = 41 @ 7300' Datum MD = 9890' Datum TV D = 8800' SS 10 NGI-14 13-3/8" CSG, 72#, N-80, ID = 12.347" I—I 2705' Minimum ID = 3.725" @ 8160' 4 1/2" OTIS XN NIPPLE 7" TBG -PC, 26#, L-80, 0.0383 bpf, ID = 6.276" 8116' TOP OF 4-1/2" TBG PC 8116' TOP OF 7" LNR $136' 14-1/2" TBG -PC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1--1 8172' 9-5/8" CSG, 47#, L-80, ID = 8.681 " 1 $437' PERFORATION SUMMARY REF LOG: BRCS 05/31/79 ANGLE AT TOP PERF: 27@8988' Note: Refer to Production DB for historical oerf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8988-9280 O '80 &'87 3-3/8" 4 9298-9318 O 01/31/80 3-3/8" 4 9354 -9404 O 01/31/80 7" LNR, 29#, N-80, 0.0371 bpf, ID = 6.184" 1-1 9510' 101 NOTES: 2215' I-17" CAMCO BAL-O SSSV NIP, ID = 5.937" 8094' -17" BAKER G-22 SEAL LOC 80 9-5/8" X 7" BAKER FB -1 PKR 8116' I—j 7" X 4-1 /2" XO 8160' —14-1/2" XXN PLUG (10/02/10) $160' 4-1/2" OTIS XN NIP, ID = 3.725" 8171' 4-1/2" BAKER BULLNOSE SHEAROUT SUB 81-7T---I—F4 --1/2—" TUBING TAIL ELMD TT NOT LOGGED DATE REV BY COMMENTS DATE REV BY COMMENTS 06/07/79 ORIGINAL COMPLETION 10/04/10 WEC/SV SETXXN (10/02/10) 12/06/88 LAST WORKOVER 01/12/01 SIS -CS CONVERTED TO CANVAS 01/25/01 SIS -MD FINAL 101/09/021 RWKAK I CORRECTIONS PRUDHOE BAY UNIT WELL: NGI-14 PERMIT No: 178-0920 API No: 50-029-20348-00 SEC. 1, T11 N, R1 4E 2576.19 FEL 1907.86 FNL BP Exploration (Alaska) TREE = S AFETY NOTES: NGI-14 PROPOSED SPF WELLHEAD=- DRAY = C. AXELSON ELEV = KB. FLEV = 48' BP.ELEV= O -- KOP= 3400' Max Angle 9298-9318 Datum MD- 9890 Datum TVD = 8800 -SS, 9-5/8" HES ES Cementer 142,300' 300' 9-5/8" BKR ECP 2 320` 9-5/8" Bowen Casing Patch 9-5/8" 47#, L-80, Hydril 563, ID=8.681" — 2 300` 7" TBG, 26#, L-80, TC -II - Minimum ID = 3.725" @ 8160' 4 1/2" OTIS XN NIPPLE 7" TBG -PC, 26#, L-80, 0.0383 bpf, ID = 6.276" 8116' TOP OF 4-1/2" TBG -PC 8116' TOP OF 7" LNR I--1 8136' 4-1/2" TBG -PC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" H 8172' 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 8437' PERFORATION SUMMARY REF LOG: BHCS 05/31/79 ANGLE AT TOP PERF: 27@8988' Note: Refer to Production DB for historical Del data SIZE SPF INTERVAL Opn/Sgz DATE 3-3/8" 4 8988-9280 O '80 &'87 3-3/8" 4 9298-9318 O 01/31/80 3-3/8" 4 9354 -9404 O 01/31/80 7" LNR, 29#, N-80, 0.0371 bpf, ID = 6.184" 1--1 9510' I" 7" HRQ SVLN ID= 5.963" 7-5/8" TBG -IPC, 29.7#, L-80 VamTOpHC 9-5/8" X 7" Baker PKR 8096' 9-5/8" X 7" BAKER FB -1 PKR 8116' 1--17" X4-1/2" XO 8160' 1--14-1/2" OTIS XN NIP, ID = 3.725" 8171' –14-1/2" BA KER BULLNOSE SHEA ROUT SUB 8172' 4-1/2" TUBING TAIL ELMD TT NOT LOGGED DATE REV BY COMMENTS DATE REV BY COMMENTS 06/07/79 ORIGINAL COMPLETION 10/04/10 WEC/SV SET XXN (10/02/10) 12/06/88 LAST WORKOVER 01/12/01 SIS -CS CONVERTED TO CANVAS 01/25/01 SIS -MD FINAL 101/09/021 RN/KAK I CORRECTIONS PRUDHOE BAY UNIT WELL: NGI-14 PERMIT No: 178-0920 API No: 50-029-20348-00 SEC. 1, T11 N, R14E 2576.19 FEL 1907.86 FNL BP Exploration (Alaska) n L~ MEMORANDUM To: Jim Regg ~~~~ ~~t ~~lv P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Friday, August 27, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-14 PRUDHOE BAY UNIT NGI-14 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UNIT NGI-14 API Well Number: 50-029-20348-00-00 Inspector Name: John Crisp Insp Num: mitJCr100722053353 Permit Number: 178-092-0 Inspection Date: 7/21/2010 Rel Insp Num: MITOP000003203 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI-lam Type Inj. G ~ TVD 7264 IA , 340 2500 2430 II 2420 P.T.D 1780920 TypeTest SPT I TCSt pSl 1816 / OA 340 1240 1360 1440 - Intel'V814YRTST P~F P ~ TUbing 3550 3550 3550 3450 Notes: 3.8 bbls pumped for test. Test showed possible IA x OA communication. When bringing up the IA to test pressure the OA jumped from 400 psi to 800 very quickly. The OA did not track with IA pressure but test showed possible IA x OA communication. AOGCC Supervisor will make pass/fail determination. Per Jim Regg, test code will be a Pass. ;~ ~---~'~ ~`'-rZ GC-~<C'~i4, C'l,tlt.~„e ~i ~ ZZ~ I fl w~«*„" Friday, August 27, 2010 Page 1 of 1 AOGCC MITIA Forms L-222 (209119~NGI-02 (1750520), NGI-09 (1760680~NGI-14 (1780... Page 1 of 3 Regg, James B (DOA) From: Regg, James B (DOA) Friday, August 27, 2010 9:16 AM To: 'AK, D&C Well Integrity Coordinator' Sent: Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Subject: RE: MIT NGI-14 Thank you reiterating infor previously provided; I should have done a bit more research before sending. ,~ Based on what you describe, I'd hold off on admin approval request and will have MIT changed to "Pass" Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Thursday, August 26, 2010 10:15 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); AK, D&C Well Integrity Coordinator Subject: RE: MIT NGI-14 Jim, On July 22nd, Torin sent an e-mailto both Tom Maunder and yourself, with the information regarding the OA pressure build up during the MITIA and the plan to pursue an AA for IAxOA communication. On July 26th, Torin talked with Tom regarding the need for additional testing and had decided there was no need for additional testing. On August 1st, the ambient temperatures on the North Slope reached 71 degrees resulting in many wells across the field requiring bleeding due to the warm ambient temperatures, including NGI-14. During the bleed on NGI-14, Arctic Pack was encountere w ich caused plug~i~ in the needle valves used for the bleeding. I sent an a-mail to Tom and yourself on August 1st stating the intent to perform an Arctic Pack dump on the surface casing, and then monitor the well with the DHD crew for an additional 20 days. During this time we have seen no indications of pressure build on the IA and OA. I am enclosing the TIO plot per your request. .----- I know that Torin has written the request for the AA and was sent to Anchorage on 8-12 for Harry Engel and Steve Rossberg to sign and submit. The well has not been retest, based on what Torin and Tom had discussed. The well has shown no pressure build ups and has not had a bleed since the pressure bleeds from the high ambient temperatures. Please advise if you believe additional evaluation is required Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 8/27/2010 AOGCC MITIA Forms L-222 (209119~NGI-02 (1750520), NGI-09 (1760680 NGI-14 (1780... Page 2 of 3 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, August 26, 2010 1:54 PM To: AK, D&C Well Integrity Coordinator Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Subject: MIT NGI-14 NGI-14 MIT done 7-21-10 shows a significant pressure response in OA while performing MITIA; BP shows test as pass, Inspector reports this as an Inconclusive test (attached) Has this well been retested? Has there been any diagnostics done to evaluate the high OA pressure; possible IAxOA communication? Please provide 6 month TIO plot Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Brooks, Phoebe L (DOA) Sent: Thursday, August 26, 2010 1:06 PM To: Regg, James B (DOA) Subject: FW: AOGCC MITIA Forms L-222 (2091190), NGI-02 (1750520), NGI-09 (1760680), NGI-14 (1780920), PSI-06 (2020790), PSI-08 (2021720), PSI-09 (2021240), PSI-10 (2021590), S-104 (2001960), V-227 (2091160), Y-11 (2051640) Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone:907-793-1242 Fax: 907-276-7542 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Sunday, August 01, 2010 10:43 PM To: AK, D&C Well Integrity Coordinator Cc: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: AOGCC MITIA Forms L-222 (2091190), NGI-02 (1750520), NGI-09 (1760680), NGI-14 (1780920), PSI-06 (2020790), PSI-08 (2021720), PSI-09 (2021240), PSI-10 (2021590), 5-104 (2001960), V-227 (2091160), Y-11 (2051640) Jim, Tom and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: L-222 (PTD #2091190) NGI-02 (PTD #1750520) NGI-09 (PTD #1760680) NGI-14 (PTD #1780920) PSI-06 (PTD #2020790) PSI-08 (PTD #2021720) PSI-09 (PTD #2021240) 8/27/2010 AOGCC MITIA Forms L-222 (209119~NGI-02 (1750520), NGI-09 (1760680 NGI-14 (1780... Page 3 of 3 PSI-10 (PTD #2021590) S-104 (PTD #2001960) V-227 (PTD #2091160) Y-11 (PTD #2051640) «July 2010 MIT forms GPB part 2.zip» Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 8/27/2010 PBU NGI-14 PTD 1780920 8/26/2010 TIO Pressures Plot 4,000 3.000 2,000 1,000 Wep: NGI-14 '"'~- Tbg IA -~- OA OOA --a~-- OOOA On • f 1 LJ 02!27110 03/13/10 0312"1110 Ud110110 Od.12~110 05/OS1110 0`at22J10 00/05/10 06119/10 07!03/10 07117.%10 0'31110 09J1d:'10 ~ ! MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 27, 2010 TO: Jim Regg C~ P.I. Supervisor (\~~ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-14 FROM: John Crisp PRUDHOE BAY UNIT NGI-14 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed B P.I. Suprv--~'~' Comm Well Name: PRUDHOE BAY UNIT NGI-14 API Well Number: 50-029-20348-00-00 Inspector Name: John Crisp Insp Num: mitJCr100722053353 Permit Number: 178-092-0 Inspection Date: 7/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGIaa ~ Type Inj. G ' TVD 7264 ~ IA 340 2500 ~ 2430 2420 - P.T.D 1780920, iTypeTest SPT Test psi 1816 QA 340 1240 1360 1440 Interval aYRTST p~F t ~ Tubing 3550 3SS0 3SS0 3450 Notes: 3.8 bbls pumped for test. Test showed possible IA x OA communication. When bringing up the IA to test pressure the OA jumped from 400 psi to 800 very quickly. The OA did not track with IA pressure but test showed possible IA x OA communication. AOGCC Supervisor will make pass/fail determination. _ S2Q f ~- ti ~z ~C~ C~~~ v~ ~ ~ ~ ~ E ~~CU~ ~/~ U I `~ ~ tL~'y - l¢ Tuesday, July 27, 2010 Page 1 of 1 Injector NGI-14 (PTD #1780920) IAx~ communication noticed during AOG~MITIA Page I of 2 Regg, James B (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, July 26, 2010 3:02 PM To: AK, D&C Well Integrity Coordinator Cc: Regg, James B (DOA) Subject: RE: Injector NGI-14 (PTD #1780920) IAxOA communication noticed during AOGCC MITIA Torin, Do you have copies of what pressure tests/observations were accomplished? The AA request should be submitted as soon as you can. Keeping the well in operation is possible, however you need to provide your mitigation/observation plan. Please note an AO high pressure pilot will be required as has been on other gas injectors with IA x OA communication. look forward to your reply. Tom Maunder, PE AOGCC From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Monday, July 26, 2010 2:53 PM To: Maunder, Thomas E (DOA); AK, D&C Well Integrity Coordinator CC: Regg, James B (DOA) Subject: RE: Injector NGI-14 (PTD #1780920) IAxOA communication noticed during AOGCC MITIA Tom, The well is currently on injection right now. It's been concluded that the well has IAxOA communication. If you approve, BPXA's plan forward is to keep the well on injection while an Administrative Approval is pursued. Torin From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, July 26, 2010 2:32 PM To: AK, D&C Well Integrity Coordinator Cc: Regg, James B (DOA) Subject: RE: Injector NGI-14 (PTD #1780920) IAxOA communication noticed during AOGCC MITIA Torin (or Gerry), What is the status on NGI-14? Jim related that you and he had talked last week after the anomalous OA pressures during the MIT. I understand the well is on line for diagnostics. It is best that reso-utions/determinations are made as soon as practical. Will that be accomplished before the end of this week? I look forward to your reply. Tom Maunder, PE AOGCC From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Thursday, July 22, 2010 12:25 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: Injector NGI-14 (PTD #1780920) IAxOA communication noticed during AOGCC MITIA Jim/Tom, Injector NGI-14 (PTD #1780920) passed a 4-year regulatory MITIA on 07/21/10. However, the OA 7/27/2010 .Injector NGI-14 (PTD #1780920) IAx~ communication noticed during AOG~MITIA Page 2 of 2 pressure built up from 340 to 1410 psi during the test. If approval is granted, the plan forward is to keep the well on injection while an AA is pursued for IAxOA communication. A TIO plot, wellbore schematic and MIT form have been included for your reference. «NGI-14 TIO Plot 07-22-10.doc» «NGI-14.pdf» «MIT PBU NGI-14 07-21-10.x1s» Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 7/27/2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI ON Mechanical Integrity Test Email to:jim.regg~alaska.gov; phcebe.brooks~alaska.gov; tom.maunder~ataska.gov; doa.aogcc.prudhce.bay~alaska.gov OPERATOR: BP F~cploration {Alaska), lnc. FIELD /UNIT /PAD: Prudhoe Bay /PBU /NGI Pad DATE: 0721/10 OPERATOR REP: Torin Roschinger AOGCC REP: John Crisp Packer Pretest Initial 15 Min. 30 Min. Weil NGI-02 T In'. G TVD 7,289' Tu - 3,000 3,000 3,000 3,000 Interval P.T.D. 1750520 T test P Test 182225 Cali 500 2,500 2,490 2,520 P/F Notes: AOGCC MIT-IA to 2500 psi for 4 year UIC OA 130 140 148 140 45 minute results: T-30001-2520 0-140 Pin 2 bbis MEOti to achieve test Well NGI-09 T In'. G TVD 7,492' Tubi 3,500 3,500 3,500 3,500 Interval P.T.D. 1760680 T test P Test 1873 Casi 340 2,500 2,520 2,520 P/F Notes: AOGCC MIT-IA to 2500 psi for 4 year UIC OA 20 20 20 20 45 minute results: T-3500 i-2520 0-20 Well NGI-14 T In . G TVD 7,264' Tu ' 3,550 3,550 3,550 3,450 Interval P.T.D. 1780920 T test P Test 1816 340 2,500 2,430 2,420 P/F Notes: AOGCC MIT-IA to 2500 psi for 4 year UIC OA 340 1,240 1,360 1,440 P f-1~~~a ~g~~ P '° `~~a Well T In . TVD Tubi Interval P.T.D. T test Test P1F Notes: OA P.T.D. T test Test Cali P/F Notes: OA TYPE INJ Codes TYPE TEST Codes D =Drilling Waste M =Annulus Monitoring ~,~,,, ~ . ~ ~x m>;w• ~• ~~ l,7 '_ t } F/ ~J ~, ~*'' G =Gas P =Standard Pressure Test I =Industrial Wastewater R = Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomay Survey W =Water D = DilFerentiad Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU NGI-02, 09, 14 07-21-10.x1s NGI &LPC injector due for UIC ~ng Maunder, Thomas E (DOA) From: AK, RES GPB East Production Optimization Engineer (AKRESGPBEastProductionOptimizationEngineer@bp.com] Sent: Tuesday, July 13, 2010 8:32 AM To: Maunder, Thomas E (DOA) Subject: RE: NGI &LPC injector due for UIC testing Hello Tiffany, Page 1 of 2 I assume these are the plants the State is referring to. I would take these dates as best estimates. GC1 is online now. LPC 7/14 startup GC1 Online as of 7/10 CGF Shut-down 7/15 - 8/6 Byron Jackson (alt. Ryan Rupert) GPB East Production Optimization Engineer 907.659.5923 office x2409 harmony AK, RES GPB East Production Optimization Engineer .~ r„aµ , ,,: ~ ~, , ~ °~ r ~' Q 1~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 13, 2010 8:25 AM To: AK, D&C Well Integrity Coordinator Cc: AK, RES GPB East Production Optimization Engineer; Brooks, Phoebe L (DOA) Subject: RE: NGI &LPC injector due for UIC testing Thanks Tiffany. What is the anticipated schedule for bringing the plants back on line? Tom Maunder, PE AOGCC From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Monday, July 12, 2010 7:34 PM To: Maunder, Thomas E (DOA); AK, D&C Well Integrity Coordinator Cc: AK, RES GPB East Production Optimization Engineer Subject: NGI &LPC injector due for UIC testing Thomas, Per our conversation, the following injectors are due for UIC compliance testing and shut in due to facility work. The wells will be put back on injection as the plants are brought back on line. Once thermally stable, we will proceed with AOGCC witnessed MIT-IA's. There are no known downhole integrity issues with any of these injectors. NGI Gas Injectors: NGI-02 (PTD #1750520) NGI-09 PTD #1760680) NGI-14 (PTD #1780920) 7/13/2010 NGI &LPC injector due for UIC ng ~ Page 2 of 2 LPC SWI injector: P1-21 (PTD #1930590) Please contact Well Integrity with any questions or concerns. Thank you, Tiffany Quy (for the Well Integrity Coordinator Gerald Murphy/Torin Roschinger) Projects Well Integrity Engineer phone: (907) 659-5102 cell: (253) 576-6153 tiffg0@bp.com 7/13/2010 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ,~ 1 (C?N ( . ~ ' -? 7 --' .:¡,. l '-''/ )I...:Lo DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-14 PRUDHOE BAY UNIT NGI-14 i l <if - oq ~ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv SgjZ- Comm NON-CONFIDENTIAL Well Name: PRUDHOE SAY UNIT NGI- 1 4 API Well Number 50-029-20348-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060711204440 Permit Number: 178-092-0 Inspection Date: 7/8/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. _. ¡Type Inj.1 G 1 TVD : -- Well i NGI-14 7264 I IA I 95 2000 1880 i 1860 , P.T. ! Î780920 :TypeTest I SPT ! Test psi : 1816 ! OA ! 0 10 10 ! 10 ../ T b' I I Interval 4YRTST P/F P u 109 3600 3600 3600 I 3600 Notes 5.8 bbls diesel pumped. 1 well house inspected; no exceptions noted. 8 Wednesday, July 12, 2006 Page I of I TREE: WELLHE;AD: ACTUA TOR: KB. ELEV : BF. ELEV : KOP= Max Angle: Datum MD = OatumlVD= GRAY AXELSON 48' NGI-14 SAFETY NOTES: r 3400' 41 @ 7300' 9890' 8800' 5S <8 2215' --17" CAMeO BAL-O SSSV NIP, ID = 5.937" I 113-3/8" CSG, 72#, N-80, 10 = 12.347" I Minimum 10 = 3.725" @ 8160' 41/2" OTIS XN NIPPLE 8094' 7" BAKER G-22 SE;AL LOC 8096' -19-5/8" X 7" BAKER FB-1 PKR I 17" TBG-PC, 26#, L-80, 0.0383 bpf, ID: 6.276" I TOP OF 4-1/2" TBG-PC H 8116' -17" X 4-112" XO I TOP OF 7" LNR I -14-1/2" OTIS XN NIP, ID: 3.725" I 14-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I -14-1/2" BAKER BULLNOSE SHE;AROUT SUB -14-1/2" TUBING TAIL I 1-1 ELMD TT NOT LOGGED 19-5/8" CSG, 47#, L-80, ID: 8.681" I PERFORA TION SUMMARY REF LOG: BHCS 05/31/79 ANGLEAT TOP PERF: 27 @ 8988' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 3-3/8" 4 8988 - 9280 0 '80 & '87 3-3/8" 4 9298 - 9318 0 01131/80 3-3/8" 4 9354 - 9404 0 01/31/80 17" LNR, 29#, N-80, 0.0371 bpf, ID = 6.184" H 9510' DATE 06/07/79 12/06/88 01/12/01 01125/01 01/09/02 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER SIS-CS CONVERTED TO CANVAS SIS-MD FINAL RNIKAK CORRECTIONS DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: NGI-14 PERMIT No: 178-0920 API No: 50-029-20348-00 SEC. 1, T11N, R14E2576.19 FEL 1907.86 FNL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor COL Chair THRU: Tom Maunder P.I. Supervisor FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL DATE: June 1, 2002 SUBJECT: Mechanical Integrity Tests '',,l~-t~©~'~ 07,09,13 & 14 Prudhoe Bay Field Prudhoe Bay Unit Packer Depth Pretest Initial 15 Min. 30 Min. WellI NGI-07 I Typelnj. I G I T.V.D. J 7398 I Tubing I 3360 I 3360 J 3360 I 3360 I lntervall 4' P.T.D.I 1760380 TypetestI P ITestpsil 1850 ICasingI 280 I 2040 I 20301 20301 P/F I -P Notes: WellI NGI-09 I Typelnj. I G I T.V.D. 17510 I Tubing 13550 I 3550 i ~o i ~o [IntervalI 4 P.T.D.I 1760680 Type testI P I Testpsil 1878 I Casingl 300 I 2450 I 245,0I'2450 I PIE I -P, , Notes: WellI NGI-13 I Typelnj.I G J T.V.D. I 7344 I Tubingl 3550 I 3550 ! 3550 I 3550 I lntervall 4 P.T.D.I 1780910 ITypetestl P ITestpsil 1836 ICasingI 80 I 2500 I 2490 I 2500 I PIE I -P Notes: ,, We,,I I Type,nj.I 1 I Tubingl 0 I I I lntervall 4 P.T.D.I 1780920 ITypetestl P ITestpsil 1.'~93 I Casingl 50 I 25601 23301 2300 I P/F I -P" Notes: WellI Type Inj. P.T.D. I Type test Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BP's Prudhoe Bay Field NGI Pad to witness 4 year MIT's. Good tests, no failures or problems witnessed. M.I.T.'s performed: 4 Attachments: Number of Failures: 0 -- Total Time during tests: 3 hrs. CC: MIT report form 5/12/00 L.G. MIT PBU NGI 06-01-02jc.xls 6~4~02 , STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ¢ .... '~'~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS ~ SUSPENDED ~J ABANDONED ~ SERVICE~ Gas Injector 2. Name of Operator ARCO Alaska; Inc. 3. Address P_O_ Box 100360, ^nchor~ge, AK 99510-0360 4. Location of well at surface 606' FSL, 816' FWL, Sec. 1, T11N, R14E, UM At Top Producing Interval 2093' FNL, 2549' FWL, Sec. 1, TllN, R14E, UM At Total Depth 1911' FNL, 2575' FEL, Sec. 1, T11N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 48' I ADL 28302 12. Date Spudded 113. Date T.D. Reached 14. Date Comp., Susp. or Aband. 05/14/79 I 06/01/79 06/07/79* 17. Total Depth (MD+TVD) 118.Plug Back Depth (MD+T~/D) 19. Directional Survey 9515'MD/8515'TVD I 9469'MD/8474'TVD YES [] NO [] 7. Permit Number 78-92 8. APl Number 50- 029-20348 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number NGI -14 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 15. Water Depth, if offshore 116' No. of Completions N/A feet MSL] 1 20. Depth where SSSV set 21. Thickness of Permafrost 2215' feet MD 1900' (approx) 22. Type Electric or Other Logs Run D I L/SP ~ BHCS/GR ~ FDC/CNL/CCL/GR/CAL, RFT,CNL/GR/CCL,Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP I BOTTOM 20" 94.0# H-40 Surf I 79 ' 13-3/8" 72.0# L-RO S~rf ?705 ' 7" 26.0# L-80 8136' Ii9510' I 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) See attached sheet HOLE SIZE 7-1/?" ! ?-1/4" 8-1/2" CEMENTING RECORD 277 700 ~25 sx Class AMOUNT PULLED 25. TUBING RECORD SIZE DEPTH SET (MD) I PACKER SET (MD) 7"/~.- !/2" 8! 72 ' J 8096' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) /AMOUNT& KIND OF MATERIAL USED ;ee report of Sundry ~ell Operations dated 9/25/87, for Stlimulation data. 27. N/A PRODUCTION TEST Date First Production Date of Test Flow Tubing Press. 28. JHours Tested Casing Pressure j Method of Operation (Flowing, gas lift, etc.) TEST PERIOD e CALCULATED , OIL-BBL GAS-MCF WATER-BBL 24-HOUR RATE I~ CORE DATA ! CHOKE SIZE IGAS'OILRATIO I OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None * NOTE: Perforated well 2/14/80. Stimulated well 8/24/87. Added perforations 5/24/81. -'"'~'~chorage ..' Form 10407~ ' 0 Rev. 7-1-80 C5/ 69 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top Sadl erochit Base Sadlerochit 8984' 9415' 8041' 8425' N/A 31. LiST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed / , Title Regional Drilling Engineer 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~ lng 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 WC5/069 WELL COMPLETION OR RECOMPLETION REPORT AND LOG (Continued) NGI-14 Item 24 8988 9016 9044 9080 9112 9158 9203 9250 9298 9354 9374 Perforation Depths MD TVD -9014 -9042 -9078 -9110 -9156 -9196 -9248 -9280 -9318 -9374 -9404 8044' 8069 8094 8127 8155 8196 8236 8277 8320 8370 8388 -8068 -8092 -8125 -8153 -8194 -8230 -8276 -8304 -8337 -8388 -8415 WC5/069 '" Anchorage STATE OF ALASKA '-- AL/-,,.,.,,A el L AND GAS CONSERVATION COM M IS,.,. ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging __ Pull tubing __ Alter casing __ Repair well __ Pull tubing 2. Name of Operator I 5. Type of Well: ARC0 A1 aska, Inc. I Development__ Exploratory 3. Address .... Stratigraphic P. 0. Box 100360, Anchorage, AK 99510-v~ou Service,' Pedorate __ Other Workover 6. Datum elevation(DForKB) RKB 48' Z UnitorPropedyname Prudhoe Bay Unit 4. Location of well at surface 606' FSL, 816' At top of productive interval 2093' FNL, 2549' At effective depth 1952' FNL~ 2614' At total depth 1911 ' FNL, 2575' FWL, Sec.1, T11N, R14E, UM FWL, Sec.1, T11N, R14E, UM FEL, Sec.1, T11N, R14E, UM FEL, Sec.1, T11N, R14E, UM 8. Well number NC.!-!4 9. Permit number/approval number 78-92/8-692 10. APl number 50-- 029-20348 11. Field/Pool Prudhoe Bay Field 12. Present well condition summary Total depth: measured true vertical Effective depth' measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length 79' 2673' 8411' 1374' 951 5' MD feet 8515'TVD feet 9469'MD feet 8474 ' TVD feet Plugs (measured) Junk (measured) Size Cemented 20" 277 sx AS 13-3/8" 7260 sx AS 9-5/8" 700 sx Class G & 300 sx AS ! 7" 425 sx Class G See Attached Sheet None None Measured depth True vertical depth 79'MD 79'TVD 2705'MD 2705'TVD 8437'MD 7559'TVD 8136'-9510'MD/7299'-8510'TVD true vertical Tubing (size, grade, and measured depth) 7"/4-1/2", L-80, tbg w/tail ~ 8172' Packers and SSSV (type and measured depth) Baker 'FB-I' pkr ~ 8096' & cAMCo 'BAL-O' SSSV @ 2215' 13. Stimulation or cement squeeze summary N / ^ Intervals treated (measured) Treatment description including volumes used and final pressure Alaska, J)ii & Gas Cons, C0.mmisr,; :~, 14. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas __ Suspended __ Service Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed / , Title Rog~on~! Form 10-404 Rev 06/15/~8 *WorkVover Well Hi story 5W03/083 SUBMIT IN DUPEICA~TE feet 88£8- 9Z28- 0628- 1~618- 6§I8- 260~- ~90~- 8868 0Z68 0268 9618 ~608 6908 ~0~6- ~Z66- 8166- 0826- 8~26- 9616- 9§I6- 0II6- 8Z06- ~I06- ~Z~6 ~§~6 0§26 ~OZ6 8§I6 ZlI6 0806 ~06 9106 8868 GAl sq2dao uo.~eJo~ad ~I-IgN (panu~uo3) suo~2eJado LLaM £Jpuns ¢o %Joda~ ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty. parish or borough , ~QC'_O~T.~_~_ T_N~- I NORTH _~LO?E Field ILease or Unit Auth. or W.O, no, }Title -~_-~ 257 2 I WORKO%~_?. l stat~K MC!-!~. [Well no. Operator _~I _' 50-029-203~. 9 Spudded or W.O. begun }Date ~cC~o~ I 11/2!/8_~ Date and depth Complete record for each day reported as of 8:00 a.m. ~r11'~ m 4 11/22/88 ( TD: 9515 PB: 9469 SUPV:TJ 11/23/88 ( TD: 9515 PB: 9469 SUPV:RB 11/24/88 ( TD: 9515 PB: 9469 SUPV:BB 11/25/88 ( TD: 9515 PB: 9469 SUPV:BB 11/26/88 ( TD: 9515 PB: 9469 SUPV:BB 11/27/88 ( TD: 9515 PB: 9469 SUPV:BB 11/28/88 ( TD: 9515 PB: 9469 SUPV:BB 11/29/88 ( TD: 9515 PB: 9469 SUPV:BB IHour 0600 IARCO w.I NU BOPE MW: 9.2 NaCl RU CHOKE, ACCEPT RIG @ 0600 11/21/88. PULL BPV, PUMP 100 BBL CRUDE, 400 BBL SEAWATER, 73 BBL TEMBLOK 120, 305 BBL 9.2 NACL, MONITOR TUBING & WO TEMBLOK, BLEED ANNULUS, MONITOR WELL, SET BPV, ND TREE & NU BOPE. DAILY:S84,643 CUM:$84,643 ETD:S84,643 EFC:$748,000 RD DRESSER MW: 9.2 NaCl NU BOPE, ATTEMPT TO TEST, PULL LEAKING BPV, TEST BOPE, TEST PACKOFFS, RU WIRELINE, MAKE 2 ATTEMPTS TO JET CUT TUBING @ 7969', POOH & RD WIRELINE. DAILY:S27,250 CUM:$111,893 ETD:S111,893 EFC:$748,000 POOH & LD 7" TBG MW: 9.2 NaCl RD WIRELINE, CIRCULATE OUT 10.8 BRINE, PUMP 75 BBL TEMBLOK PILL, MONITOR WELL NO FLUID LOSS, POOH LAYING DOWN 7" TUBING. DAILY:S66,387 CUM:$178,280 ETD:S178,280 EFC:$748,000 PU BHA MW: 9.2 NaC1 PULL & LAY DOWN 7" TUBING, CHANGE RAMS & TEST, BOTTOM RAMS WOULD NOT TEST. DAILY:S122,041 CUM:$300,321 ETD:S300,321 EFC:$748,000 POOH W/ 3-1/2" DP MW: 9.2 NaCl RIH W/ FTA #1, RIH ON 3-1/2" DP TO 7856', CBU, LAND DP ON TEST PLUG, CHANGE BTM PIPE RAMS, TEST TO 5000 PSI, RIH, SPEAR FISH & SHEAR PBR, POOH. DAILY:S33,174 CUM:$333,495 ETD:S333,495 EFC:$748,000 POOH MW: 9.2 NaCl LD FISHING TOOLS, RECOVERED CUT OFF 7" & PBR, MU CUTTER ON DP, RIH CUT PBR BARREL @ 8031', POOH LD CUTTER, MU SPEAR, RIH, ENGAGE PBR, PULL 30,000J OVER, POOH. DAILY:$32,174 CUM:$365,669 ETD:S365,669 EFC:$748,000 CBU MW: 9.2 NaCl POOH, NO FISH, MU NEW GRAPPLE, RIH, WORK SPEAR INTO PBR, POOH RECOVER PBR, MU 8.5" PRT, RIH, MILL PACKER, PUSH DOWN HOLE, POOH 30', PACKER FREE, CBU. DAILY:$29,811 CUM:$395,480 ETD:S395,480 EFC:$748,000 RIH W/ RTTS PKR MW: 9.2 NaCl CBU, POOH W/ PKR DRAGGING, PRT RELEASED, RIH 2 STDS & LATCH PRT, POOH DID NOT RECOVER PKR, RIH LATCH PKR @ 7416', POOH, LD PKR, RIH W/ RTTS & CLOSING FINGERS. The above is correct For *orm pro~aration and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ' ' .... ~ ~ consecutively ;Alaska Dil Page no. AR3B-459-1-D ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field ARCO ALASKA INC. C°unty°r~H SLOPE PRUDHOE IL ...... ~I-14 tstateA[ I Well no. Date and depth as of 8:00 a.m. 11/30/88 ( TD: 9515 PB: 9469 SUPV:BB 12/01/88 ( TD: 9515 PB: 9459 SUPV:TJ 12/02/88 ( TD: 9515 PB: 9459 SUPV:TJ 12/03/88 ( TD: 9515 ?B: 9459 SUPV:TJ 12/04/88 ( TD: 9515 PB: 9459 SUPV:TJ 12/05/88 ( TD: 9515 PB: 9459 SUPV:TJ 12/06/88 ( TD: 9515 PB: 9459 SUPV:TJ Comple, ...... d f~r~ ~y while drilling ..... k .... in prog .... ,1) ¸2) RIH W/ 6" MILL MW: 9.2 NaC1 RIH W/ 9-5/8" RTTS & CLOSING FINGERS, SET PKR @ 2549' & TEST CASING TO 3000 PSI, POOH & LD CLOSING FINGERS, RIH & SET PKR @ 8119', TEST CASING TO 3000 PSI FOR 30 MIN, POOH LD RTTS, MU 6" MILL & BHA, RIH. DAILY:S36,141 CUM:$479,166 ETD:S479,166 EFC:$748,000 PU PKR & TAILPIPE MW: 9.2 NaC1 TIH W/ 6" MILL, TAG FILL @ 9385', DRILL TO 9460', POOH, RU WIRELINE, RIH W/ 8.5" GR/JB TO 8106', POOH, PU PKR & TAILPIPE ASSEMBLY. DAILY:S32,189 CUM:$511,355 ETD:S511,355 EFC:$748,000 RIH W/ PRT MW: 9.2 NaC1 RIH W/ PKR ON WIRELINE TO 4000', PKR WOULD NOT GO DOWN, POOH, RIH W/ 8.5" GR/ JB TO 8106', RIH W/ PKR ON DP, COULD NOT GET PAST 5635', POOH, PKR HUNG UP ON LOWER F.O. AT 2450', SET PKR, POOH W/ DP, PU PRT & RIH TO MILL PKR. DAILY:S42,230 CUM:$553,585 ETD:S553,585 EFC:$748,000 MILLING PKR @ 2454' MW: 9.2 NaCl RIH W/ PRT TOOL TO 2424', POOH, PU TIW SEAL ASSY, STING INTO PKR & SHEAR OUT S.O.S., CBU, POOH, RIH W/ PRT TOOL, MILL ON PKR @ 2454'. DAILY:S29,555 CUM:$583,140 ETD:S583,140 EFC:$748,000 L.D. BMA MW: 9.2 NaC1 MILL UP PKR, CBU, POOH LD PKR & FISHING TOOLS, RIH W/ 9-5/8" SCRAPERS TO 8126', CBU, POOH, LD SCRAPERS & TAILPIPE. DAILY:S37,056 CUM:$620,196 ETD:S620,196 EFC:$748,000 TESTING 7" RAMS MW: 9.2 NaCl RIH W/ 9-5/8" PKR, SET PKR @ 8080' (WLM), TEST CSG & PKR TO 2500 PSI, POOH LDDP, CHANGE RAMS & TEST SAME. DAILY:S37,222 CUM:$657,418 ETD:S657,418 EFC:$748,000 SPACING OUT TBG MW: 9.2 NaC1 CHANGE RAMS TO 7",PULL WEAR RING, TEST RAMS, RIH W/ 7" TBG & SEAL ASSEMBLY, STING INTO PKR, SPACE OUT & LAND TBG. (CAMCO 'BAL-O' SSSV @ 2215', BAKER 'FB-I' PKR @ 8096', & TT @ 8172') DAILY:$216,154 CUM:$873,572 ETD:S873,572 EFC:$748,000 The above is correct .. For form ~reparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Title& AR3B-459-2-B INumber all daily well history forms consecutively lPage no as they are prepared for each well. [ ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequent a y Attach descr pt on of all cores Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not tess requently than every 30 days, or 2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin~ until completion, District County or Parish I StateA ARCO ALASKA INC. NORTH SLOPE K Field Lease or Unit [Well no. P RUDHOE NGI - 14 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. AUDI 4 6) 12/07/88 ( TD: 9515 ?B: 9459 SUPV:TJ TEST TREE MW: 9.2 NaC1 MU TBG HGR, DISPLACE TO SEAWATER, FREEZE PROTECT TBG & ANNULUS, LAND TBG, PERFORM M~!~', ND RENTAL STACK, MU WSR STACK, TEST TREE TO 5000 PSI. DAILY:S87,625 CUM:$961,197 ETD:S961,197 EFC:$748,000 The above is correct For preparation and distribution ./ see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms Consecutively IPage no. as hey are prepared lor each well. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code County or Parish /StP Lease NORTH SLOPE t~K Field PRUDHOE or~i~: 28302 NGI-14 WeU no, T t e WORKOVER District ARCO ALASKA INC. Auth. or W.O.,1{~.2572 Operator ARCO Spudded or WA~,.~, Pate and depth as of 8:00 a.m. 12/08/88 ( 1' TD: 9515 PB: 9459 SUPV:BB API: 50-029-20348 IA'R'C°'~'.O000 pate 11/21/88 Complete record for ~ch day repo~ed AUDI 4 Iotal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our 0(;00 MRS IPrior status if a W.O. 1 RIG RELEASED MW: 9.2 NaC1 TEST TREE TO 5000 PSI, ATTEMPT TO TEST TBG TO 4000 PSI, S.O.S. SHEARED @ 3900, TEST ANNULUS TO 3000 PSI, SET BPV, RELEASED RIG @ 1200 MRS 12/7/88. DAILY:S6,812 CUM:$968,009 ETD:S968,009 EFC:$748,000 Old TD Released rig New TD J PB Depth IDate Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date I Reservoir Producing Interval Oil or gasTest time Production Oil on teat Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section t0, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPage no. DIvlNon of AtlanlicRIchfleldCompany ..... STATE OF ALASKA --' A IJ-,,.,KA OIL AN D GAS CONSERVATI ON COM M lb..,, ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ v// Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging.__ Time extension __ Stimulate __ Change approved program __ Pull tubing ~ Variance m Perforate __ Other _.~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510' 4. Location of well at surface 606' FSL, 816' At top of productive interval 2093' FNL, 2549' At effective depth 1952' FNL, 2614' At total depth 1911 ' FNL, 2575' 5. Type of Well: Development Exploratory Stratigraphic 03 60 Service FWL, Sec.1, T11N, R14E, UM FWL, Sec.1, T11N, R14E, UPI FEL, Sec.1, TllN, R14E, UM FEL, Sec.1, TllN, R14E, UM 6. Datum elevation (DF or KB) RKB 4.8 ' 7. Unit or Property name Prudhoe Ba;f Unit 8. Well number NGI-14 9. Permit number 78-92 10. APl number 50-- 029-20348 11. Field/Pool Prudhoe Bay Field feet 12. Present well condition summary Total depth: measured true vertical 9515'MD feet 8515'TVD feet Plugs (measured) None Effective depth: measured 9469 ' MD feet true vertical 8474 ' T V D feet Junk (measured) None Casing Length Size Structural Conductor 79 ' 2 0" 2673 ' 13-3/8" Surface Intermediate Production 8411 ' 9 - 5 / 8" Liner 1374' Perforation depth: measured Cemented Measured depth True vertical depth 277 sx AS 79'MD 79'TVD 7260 sx AS 2705'MD 2705'TVD See Attached Sheet 700 sx Class G & 300 sx AS ! 425 sx Class G 8437'MD 7559'TVD true vertical Tubing (size, grade, and measured depth) /~ - ~"/~ ¢ /9 30~¢'/ 7", 26·0#/ft, L-80 tubing w/tail (~ 8031' Packers and SSSV (type and measured depth) Otis RPB Landing Nipple @ 2191', Baker SB-2 Hydroset packer ~ 8011' 13. Attachments 8136 ' -951 0 ' MD/7299 ' -851 0 ' TVD RECEIVED .0il & Gas Cons. ' Anchorage Description summary of proposal ¢'" Detailed operations program BOP sketch 14. Estimated date for commencing operation November 6~ 1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil m Service Gas __ Suspended __ Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~..,,, Title Associate Enqineer Date //J FOR COMMISSION USE ONLY ( I ¢, ~ ~ & ~t / q n ~ ~ Conditions oF'approval: Notify Commission so representative may witness ........... 1,&,pproval No. Plug integrity ~ B ,OP/Test ~ Location clearance m, Mechanical Integrity Test_)(_.. Subsequent form required 10-,z/;o ~--- Approved Copy Returned ~ / . ORIGINAL SIGNED BY 7' '~;' ~ Approved byorderoftheCommissioner I.f)NNIE (;. SMITH ~ uu,,,,,,~s~oner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE NGI-14 Block 12 Perforation MD 8988 -9014 9016 -9042 9044 -9078 9080 -9110 9112 -9156 9158 -9196 9203 -9248 9250 -9280 9298 -9318 9354 -9374 9374 -9404 Depths TVD 8044 -8068 8069 -8092 8094 -8125 8127 -8153 8155 -8194 8196 -8230 8236 -8276 8277 -8304 8320 -8337 8370 -8388 8388 -8415 SA3/OO36a PRUDHOE BAY NGI-14 WORKOVER PROCEDURE SUMMARY OBJECTIVE: REPAIR SHALLOW 7" TUBING LEAK BY REPLACING 7" TUBING AND HANGER. 9 5/8" PACKER WILL ALSO BE REPLACED. 1. RU SL PULL SSSV. ROUND TRIP GAUGE RING. 2. SET BPV. 3. MIRU WW1. 4. BULL HEAD TEMBLOCK PILL TO PERFS. 5. PUNCH HOLES IN TUBING. 6. CIRC HOLE WITH 8.9 PPG KILL WT BRINE. 7. ND TREE, NU BOP'S WITH EXTRA RAM. 8. POOH, LD 7" TBG + COMP EQUIPMENT. 9. PU DP + RIH MILL PACKER. 10. POOH, RECOVER PACKER. 11. RIH W/TEST PACKER. TEST 9 5/8" CASING TO 3000 PSI. 12. RIH W/6" BIT, CLEAN OUT TO 9469' PBTD. 14. POOH, LDDP. 15 RIH W/NEW 7" COMPLETION. , .... '~,.o (~I a c',~s tons. 16. SET P~, ~ST ~G, ~ST CSG, S~AR PBR, L~ TBG. 17. SET BPV, ND BOP'S, NU + TEST TREE. 18. RELEASE RIG. J.P. SCHUMACHER SR. DRILLING ENGINEER 8~22/88 ANNULAR PREVENTER 6 PIPE RAMS 5 BLIND RAMS 4 TUBING HEAD 2 1. 13-3/8" CASING HEAD 2, 9-5/8" CASING HEAD ;5.5000 PSI TUBING HEAD 4, 1;5-5/8" - 5000 PSI BLIND RAMS 5. 13-5/8" - 5000 PSI PIPE RAMS 6, 1;5-5/8" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4, TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5, INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7, INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. g. OPEN PIPE RAMS. BACKOFF RUNNING dT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI, 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11, TEST STANDPIPE VALVES TO 5000 PSI, 12, TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 1;5, RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG NOVEMBER 21, 1986 -'t i ~-1 {J W '" . i'~l] PIl~ ;H -~ N N U X X :3 i"'l U 1 1 -'~,~ U' 't,J X =t N 0 i Z,.'N_:J J.. X ~ -~: 3'B"I.[ -I -t~?J±N':I3 .~ N ~ N k N : ~ N ~ N ~ N k N NCI 1111 W. 1 ;'-t J_ 3' .[ (]. ± 13N NB:-:IZ NUJ. J..~:~IU.J,~=t,J/~I%'~ I lO:J NIj I.l.~?=tLJ.J,d.J,:d/:tt~ I li)ZI Z. NL} 11 ,wdU.:J,.~=t,::l/,::1~' I IU{3 N U 1.1. ';',~ U .J ,'-J J,'-I / ,t'l ~ I iUU N LI 1J. ~,.~ U.J ,~ -t d / ,'.:1 t2 I'"IU:J N U/' 1 ~,~ I.J.J ,.':1 =1 d/,'.:1 ~ I' ILJU N U .L J. ~ ,"J lJ_-I ,_9 .d ,:J / ,_H ~ I tLJLI I'~OIi~,.~O..-J,~J,J/,~'~ I' IUU NU 1 ±,~J Ud U_.-td/,~t~ I IULJ Z. ,'..~ ~ I"IUU Z. ( ,'d -_t ;4 U ~ ,--I ) ,.W~ I ILJLJ N LJ 1 I. ~,::t U_-J d ::1,..-I / :J ~ I ILJLI /_ ~') ~ 666 ARCO Alaska, In Prudhoe B,., Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager September 25, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: NGI-9, 13 & 14 Approval Nos. 7-477, 7-476 & 7-478 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations performed on the above-referenced wells. Very truly yours, D. F. Scheve DFS/PVL/jp Attachment cc: Standard Alaska Production Company P1 (NGI-9)W1-3 P1 (NGI-13)W1-3 P1 (NGI-14)W1-3 detailing work Gas Cons. C, ommlssk,~ WELLS/il7 ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ~: ALA.. .A OIL AND GAS CONSERVATION CCi. ,ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [~ Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Alaska: Tnt 3. Address Post Office Box 100360~ Anchoraqe, AK 99510 4. Location of well at surface 11. 606' FSL & 816' FWL, Sec. 1, T11N, R14E, UM At top of productive interval 2093'FNL & 2549' FWL, Sec. 1, T11N, R14E, UM At effective depth 5. Datum elevation (DF or KB) Feet 48' 6. Unit or Property name Prudhoe Bay Unit. 7. Well number NGI-14 (24-1-11-14) 8. Approval number 7-478 9. APl number 1952'FNL & 2614' FEL, Sec. 1, T11N, R14E, UM At total depth 1911'FNL & 2575' FEL~ Sec. 1, T11N, R14E, UM Present well condition summary Total depth: measured 9515 feet true vertical 8515 feet Effective depth: measured 9387 feet true vertical 8400 feet Casing Length Size Cemented Conductor 51' 20" Surface 2677' 13-3/8" Production 8409' 9-5/8" 50-- O?q-?n34g 10. Pool S~dlerochit Plugs (measured) Junk (measured) None 9387' - Fill Measured depth 277 sx Arcticset 2700 sx Arcticset 700 sx Class G Cmt 79' 2705' 8437' ~ue Vertical depth 79' 7559' Liner 1374' 7" 425 sx 8136'-9510' 7299'-8510 Perforation depth: measured 8988-9014', 9016-9042', 9044-9078', 9080-9110 9158-9196', 9203-9248', 9250-9280', 9298-9318', 9354-9374', 9374-9404 true vertical 8044-8068', 8069-8092', 8094-8125', 8127-8153 8196-8230', 8236-8276', 8277-8304', 8320-8337', 8370-8388', 8388-8415 Tubing (size, grade and measured depth) 7", 29#, L-80, ABM 8rd to 8003 'MD Packers and/~,S~SV (type and measured depth) RE 9-5 x 7" Baker SB-2 Packer @ 8015'MD/Otis SSSV fa 219.5'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ' 9112-9156' I ' 8155-8194' I CEIVED Alaska 0il & Gas Cons. Commission 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure -- 171 .... 199 Tubing Pressure 3900 3900 14. Attachments Daily Report of Well Operations '~' Copies of Logs and Surveys Run L-] best of knowledge 2 15. I hereby certify that the foregoing is true and correct to the my ,--~'- %7 ~ ~ ~, - Signed ~,~2~~--_.~~ Title Form 10-404 Rev. 12-1-85 I~I~T_ 1.4/~;T~T1 ¢:;; P ~1 Operations Engineering Mana.qer Submit in Duplicate DRILL SITE NGI-14 SELECTIVE STIMULATION On August 24, 1987, the following treatment was performed on NGI-14: 1. MI and RU pump truck and transports. 2. Rolled all acid compartments. 3. Pumped the following fluids: me B. C. D. E. Me G. H. I. K. L. M. Ne 2000 gals of xylene 1900 gals of 15% HCl w/additives 3800 gals of 12% HC1-3% HF w/additives 3800 gals of 2% NH,C1 water w/additives 1100 gals of 2% NH~C1 water gelled to a viscosity of 100 cop w/CMHEC and 1100 lbs of benzoic acid flakes 2000 gals of 15% HC1 w/additives 3900 gals of 12% HC1-3% HF w/additives 3900 gals of 2% NHAC1 water w/additives 1100 gals of 2% NH[C1 water gelled to a viscosity of 100 cop w/CMHEC and 1100 lbs of benzoic acid flakes 4000 gals of 15% HCl w/additives 8000 gals of 12% HC1-3% HF w/additives 8000 gals of 2% NH4C1 water w/additives 2000 gals of 2% NH,C1 water gelled to a viscosity of 100 cop w/CMHEC and 2000 lbs of benzoic acid flakes 1000 gals of 15% HC1 w/additives 2000 gals of 12% HCl-3% HF w/additives 2000 gals of 2% NH4C1 water w/additives 100 bbls of methanol 4. RD and released equipment and returned well to injection. 5. Tested well for new injection capacity. RECEIVED, ,~daska Oil & Gas Cons,, Anehor~qe WELLS/Il74 STATE OF ALASKA AL, .~A OIL AND GAS CONSERVATION CC. ,¢IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging ~ Perforate ~ Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Alaska~ ]:nc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 606' FSL & 816' FWL, Sec. 1, TllN, R14E, UM At top of productive interval 2093'FNL & 2549' FWL, Sec. 1, T11N, R14E, UM At effective depth 1952'FNL & 2614' FEL, Sec. 1, T11N, R14E, UN At total depth 1911'FNL & 2575' FEL, Sec. 1, T11N, R14E, UN 5. Datum elevation (DF or KB) 48' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-14 (24-1-11-14~ 8. Approval number 7-228 9. APl number 50-- 029 -20348 10. Pool Sadl erochi t 11. Present well condition summary Total depth: measured true vertical 9515 feet Plugs (measured) 8515 feet Effective depth: measured 9387 feet Junk (measured) true vertical 8400 feet None 9387' - Fill Casing Length Size Cemented Measured depth True Vertical depth Conductor 51' 20" 277 sx Arcticset 79' 79' Surface 2677' 13-3/8" 2700 sx Arcticset 2705' Production 8409' 9-5/8" 700 sx Class G Cmt 8437' 7559' Liner 1374' 7" 425 sx 8136'-9510' 7299'-851 Perforation depth: measured 8988-9014', 9016-9042' , 9044-9078' , 9080-9110' , 9112-9156' 9158-9196', 9203-9248', 9250-9280' , 9298-9318', 9354-9374', 9374-9404' true vertical 8044-8068' 8069-8092' 8094-8125' 8127-8153' 8155-8194' , , , , , 8196-8230' 8236-8276' 8277-8304', 8320-8337' 8370-8388' 8388-8415' ~bing(size, grade and measured depth} 7" 29# L-80 ^BM 8rd to 8003'M0 Packers and SSSV(type and measured depth) 9-5/8" X 7" Baker SB-2 Packer @ 8015'MD/0tis SSSV @ 2195'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 5/20/87 -- 1_23808 .... Subsequent to operation 5/27/87 -- 1_47714 .... Tubing Pressure 3725 3661 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~/~--~...~/,_.~ -~:'p Signed ~~,~~~~ Title Operations Engineering Manager Date ~~,): Form 10-40~Rev. 12-1-85 MDn I~_~ln~ Submit in Duplicate NGI-14 ADD PERFS Daily Report of Well Operations 5/23/87 PT rams/lUb to 4500 PSI. OK. Pull SSSV. RIH w/Dummy Gun, TTL, & drive down bailer. Tag bottom @ 9213'. POH. PT hardline to 4500 PSI. OK. Pump in diesel/xylene wash - spot across perfs. PT rams to 4500 PSI. PT lub to 4000 PSI. OK. RIH w/gun #2, 26' (16' & 10'), 3-3/8", 4 SPF @ 120° phasing. 5/24/81 Shoot 9186-9196' (10'). Shoot 9140-9156' (6'). POH - all shots fired. PT rams/lub to 4000 PSI. OK. RIH w/gun #3, 20' (8' & 12'), 3-3/8", 4 SPF @ 120° phasing. Shoot 9098-9110' (12'). Shoot 9034-9042' (8'). POH - all shots fired. PT lub/rams to 4000 PSI. OK. RIH w/gun #1, 22', 3-3/8", 4 SPF @ 120° phasing. Shoot 9231-9248' POH - all shots ~ired. PT l ub to 4000 PSI. OK. RIH w/gun #4, 24' (8' & 16'), 3-3/8", 4 SPF @ 120° phasing. Shoot 9062-9078' (16'). Shoot 9006-9014' (8'). POH - all shots fired. Bring well on to warmup. PT l ub/rams to 4000 PSI. OK SI. RIH w/SSSV and set @ 2167;. Test to 4500 PSI. OK POH. ARCO Alaska, Ir Prudhoe ,.._! Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 27, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: NGI-9 & 14 Permit Nos. 76-68 & 78-92 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced wells. Very truly yours, D. F. Scheve DFS/PVL/jp At ta chment cc: Standard Alaska Production Company PI(NGI-9)W1-3 PI(NGI-14)W1-3 WELL S / 117 ARCO Alaska. Inc. is a Su~3sidiary of AtlanticRichfieldCompany STATE Of ALASKA ..... AL/. .A OIL AND GAS CONSERVATION CO ~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon,,, ,~, Suspend [] Operation Shutdown [] Re-enter suspended well C~, Alter casing i_: Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate !] Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 48' RKB feet 3. Address 6. Unit or Property name Post Office Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 606' FSL & 816' FWL, Sec. 1, T11N, R14E, UM At top of productive interval 2093'FNL & 2549' FWL, Sec. 1, T11N, R14E, UM At effective depth 1924'FNL & 2591' FEL, Sec. 1, TllN, R14E, UM At total depth 1911'FNL & 2575' FEL, Sec. 1, T11N, R14E, UM 7. Well number NGT-1Zl. (24-1-11-14) 8. Permit number 78-92 9. APl number 50-- 029-20348 10. Pool Sadlerochit 11. Present well condition summary Total depth: measured true vertical 9515 feet Plugs (measured) 9469' - Cement 8515 feet Effective depth: measured feet Junk (measured) None true vertical 9469 feet 8473 Casing Length Size Cemented Measured depth True Vertical depth Conductor 51' 20" 277 sx Arcticset 79' 79' Surface 2677' 13-3/8" 2700 sx Arcticset 2705' Production 8409' 9-5/8" 700 sx Class G Cmt 8437' 7559' Liner 1374' 7" 425 sx 8136'-9510' 7299'-8510 Perforation depth: measured 8988-9008' 9016-9036' 9044-9064' 9080 9100' 9112-9142' 9158-9188' 9203-9233' 9250-9280' 9298-9318' 9354-9374' 9374 9404' true vertical 8044-8062' 8069-8087' 8094-8112' 8127-8144' 8155-8182' 8196-8222' 8236-8260' 8277-8304' 8320-8337' 8370-8388' 8388-8415' ~bing(size, grade and measured depth) 7" 29# L-80 ABM 8rd to 8003'MD Packers and SSSV ~pe and measured depth) 9-5/8" x 7 Baker SB-2 Packer @ 8015'MD/Otis SSSV @ 2195'MD 12.Attachments Description summary of proposal [] Detailed operations progr~m,: 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver August,, 1987 Date 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.~~.. ~./c. 5'c.~4¢,.,c. Title . ODerati~n_~ Fnain~ring~ ~an~g~ ....... Commission Use Only Date Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ,:~-.~.,~., '0'~'*,~<_i ~L ,:',~', v Commissioner Approval No. 7 --'¢,~ ~ by order of the commission Date~L~] ~ Form 10-403 Rev 12-1-85 Submit in triplicate DRILL SITE NGI-14 SELECTIVE STIMULATION PROCEDURE me Be e e MI and RU pump truck and transports. Stimulate the well as follows: a· f· g. h. i. j · ne 2000 gals of xylene 1900 gals of 15% HCl w/additives 3800 gals of 12% HC1-3% HF w/additives 3800 gals of 2% NHAC1 water w/additives 1100 gals of 2% NH[C1 water gelled to a viscosity of 100 cp w/CMHEC and 1100 lbs of benzoic acid flakes 2000 gals of 15% HC1 w/additives 3900 gals of 12% HC1-3% HF w/additives 3900 gals of 2% NH4C1 water w/additives 1100 gals of 2% NH,C1 water gelled to a viscosity of 100 cp w/CMHEC and 1100 lbs of benzoic acid flakes 4000 gals of 15% HCl w/additives 8000 gals of 12% HC1-3% HF w/additives 8000 gals of 2% NHAC1 water w/additives 2000 gals of 2% NHTCl water gelled to a viscosity of 100 cp w/CMHEC and 2000 lbs of benzoic acid flakes 1000 gals of 15% HCl w/additives 2000 gals of 12% HC1-3% HF w/additives 2000 gals of 2% NH,C1 water w/additives 100 bbls of methangl Volume of tubing/liner to top of perforations: Volume of tubing liner to bottom of perforations: 336 bbls 351 bbls RD and release equipment and return well to injection immediately. Test well for new injection capacity· 1 PVL/54 STATE OF ALASKA ALAS~,.. OIL AND GAS CONSERVATION COMh,.~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing Time extension [] Change approved program [] Plugging [] Stimulate ~.' Pull tubing ~ Amend order ~ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc, 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 606' FSL & 816' FWL, Sec. At top of productive interval 2093'FNL & 2549' FWL, Sec. At effective depth 1924'FNL & 2591' FEL, Sec. At total depth 1911'FNL & 2575' FEL, Sec. 1, T11N, R14E, UM 1, T11N, R14E, UM 1, T11N, R14E, UM 1, T11N, R14E, UM 5. Datum elevation (DF or KB) 48' RKB feet/ 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-14 (24-1-11-14) 8. Permit number 78-92 9. APl' number 50-- 029-20348 10. Pool Sadlerochit 11. Present well condition summary Total depth: measured true vertical Effective depth: 9515 feet 8515 feet Casing Conductor Surface Production measured 9469 true vertical 8473 Length Size 51' 20" 2677' 13-3/8" 8409' 9-5/8" Plugs (measured) feet Junk (measured) feet 9469' - Cement None Cemented Measured depth 277 SX Arcticset 79' 2700 sx Arcticset 2705' 700 sx Class G Cmt 8437' Liner 1374' 7" 425 sx True Vertical depth 79' 7559' 8136' -9510' 7299' -8510' Perforation depth: measured 8988-9008', 9016-9036', 9044-9064', 9080-9100', 9112-9142' 9158-9188', 9203-9233', 9250-9280', 9298-9318', 9354-9374', 9374-9404' true vertical 8044-8062', 8069-8087', 8094-8112', 8127-8144', 8155-8182' 8196-8222', 8236-8260', 8277-8304', 8320-8337', 8370-8388', 8388-8415' Tubing (size, grade and measured depth) 7", 29#, L-80, ABM 8rd to 8003' MD Packers and SSSV (type and measured depth) 9-5/8" X 7" Baker SB-2 Packer @ 8015'MD/0tis SSSV @ 2195'MD 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation May, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby,~rtify that the/.f~ore~oing.j~ true and correct to the best of my knowledge Signed ~[,~/'. ~~~~~ Title Operations Engineering Manager Date Commission Use Only Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity ~ BOP Test ~ Location clearance I Approval No. "~ by order of Commissioner the commission DatW' '- Form 10-403 Rev 12-1-85 MR0 (265-6810) Submit in triplicate NGI-14 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations within the Sadlerochit interval in Well NGI-14. The proposed perforation intervals are as follows: Existing Perforations Proposed Perforations Reference 8988-9008 (20') 9016-9036 (20') 9044-9064 (20') 9080-9100 (20') 9112-9142 (30') 9158-9188 (30') 9203-9233 (30') 9250-9280 (30') 9298-9318 (20') 9354-9404 (50') 9008- 9016 (8') 9036-9044 (8') 9100-9112 (12') 9188-9203 (15') 9233-9250 (17') BHCS of 5/31/79 TOTAL = 270' TOTAL = 60' A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized for this work. All perforations will be made with hollow carrier type guns at 4 shots per foot. All perforations will be made with an appropriate fluid, the perforating performed, and gas injection resumed with the wellbore load fluid being displaced into the formation. No flaring is anticipated. WELL: SURFACE LOCATION: BoTToM HOLE LOCATION: · ORIGINAL RKB: NGI #14 .... SPUD DATE: 5/14/79 606'N ~ 816'E of SW ~,. Sec. l, TllN, R14£, UM i911'S & 2575'W of NE cr. Sec. 1,'TllN, R14E, UM 48' RKB TO Gray HANGER 28' TOP OF SADLEROCHIT: 8984 , MD ALL DEPTHS ARE RKB MD Depths are to FOP of equipment AVERAGE HOLE ANGLE: 32.5~ HAXiMUM ,ANGLE: 40.75° 9 6044'- ANGLE AT TD: 28o ANNULUS FLUID: 10.2 CaCl2 w/ I0 bbl Diesel Cap 79' 20", 94~, H-40 Vetco (19.124" ID) w/ 277 sx 2170 2195 2462 t~2705 8003' 8004' 8011' 8015' 8029' 8030' 8136' 8437' 9-5/8" 8988' 9016 9044 9080 9112 9158 9203 9250 9298' 9354' 9374' ' Bottom of 7", 26#, L-80 ABIj4S (6.276" ID) ' Otis RPB Landing Nipple (5.963" ID) C mi 4 Dottom of 9-,/8 , 7#, S00-95 BTC (8.681" ID) ' 9-5/8" FO w/ 700 sx ' 9-5/8" FO ' 13-3/8", 72#, N-80 BTC (12.347" ID) w/ 7200 sx Bottom of 7", 29#, L-80 ABM 8rd (6.184" ID) Baker Anchor Nipple Baker Seal Bore Extension 9-5/8" x 7" Baker SB-2 Packer Baker Mill Out Extension (6.625" iD) Baker Shear Out Sub (4.843" ID) NO TAILPIPE Top of Liner, BOT MC Hanger - 9008 - 9036 - 9064 - 9100 - 9142 - 9188 - 9233 - 9280 - g318' - 9374' - 9404' , 47#, L-80 BTC (8.681" ID)w/ 700 sx WORKOVER-STIMULATION ?/2~/83 Water washed w/ 500 bbl 9469' PBTD 95i0' 7", 29#, ~-80 BTC (6.184" ID) w/ ~25 sx 9515' TD 1/84 . i iiii ii iii i i ii iii i ',~ 4- 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF IN I REL I NE BOP EOU I PMENT ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: May 8, 1985 Reference: ARCO Pressure Surveys 15-13 Static 4-28-85 GO 16-8 Gradient 4-7-85 Camco 17-9 Flowing Gradient 4-8-85 Camco NGI 14 HDR 4-28-85 GO Received by Pam Lambert ATO 1429C Trans 093 Chevron D& M Expl. Services Ext. Exploration Exxon Marathon Mobi 1 Mobil E & P Phillips PB Well Files R & D Sohio State of Alaska Texaco April 17, 1~80 P. O. Box 360 Anchorage, Alaska 99510 We appreciate your letter of_~_~c/!~%3_.~exP]aJning subsurface safety valve testing in Prudho~ Bay gas injeqti0n .v~lls. Our understanding is that NGI ~lls 2, 12, 13, and 14 ~ ~equipped with Otis flauper type valves. During normal operaticns these .type valves are not surface controlled. The rem~~, gas' 'injection v.~l~s .are .equi'.~ with ball type valves. We have been wi~sing initial '~tests of th~se valves prior to the ~lls being used for injection.. Al.though'these tests are impo~t, ~ are anxious to se~ how tt~se val. ves perform under operating ccnditicns. Due to the problems involved wi.th .bleeding off th~ gas during the testing, we agree that. operational testing of these valves should be d~lay~d until the gas b~ system is installed:' Therefore, ~ propose continued i .t~.~ .of new valves when first in- stalled, and witne~~ operati6na!.testing of all g-ds injectic~ valves upon oc~p~~ of the gas blc~d~ system. ~ in August. We would also appreciate a v~ll inventory, lijting the type of subsurface safety valve installed and plans, if any, .tO'i~ze the type of c~pletion used. Cx~missioner IgS/ng ~ AF1CO Oil and Gas Company ~hrch 24, 1980 ,// Reference' ARCO Pressure Surveys NGI.#11 2/19/80 Botton~ole Pressure Survey Dresser Atlas 2/12/80 Bottomhole Pressure Survey Dresser At].as ~/zPlease sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering 200 DISTRIBL~FION North Geology R&D Drilling Eng. Manager D&H Geology State of Alaska Exxon Getty Phillips Sohio ~.Iarathon C}le\rrOll )darch 18, 19~0 Reference' M~.CO Magnetic Tapes ]}.S. 3-14 12/22/79 Tape ~-:00].32 D.S. 7-8 1/21/80 Tape /!60215 1/25/80 Ta. pe ~!6020] 5/31/79 Tape ?~60063 ~Please sign and ~etu~n d~e attached copy as rec~il)t of data. K. J. Sahlstrom North Fmgineering T[bLNS~ItYI'AL ~g 151 DiSTRfBUP[ON getty Phillips Sohio ARCO Oil and Gas Company A~cl;o,a~.~'. /,,i:~s;,::~ 99510 "i' :!-:F-i~r,~ 1~ ,: 27/ 5()2~ March 13, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak 99510 Subject: DS 3-11, Permit No. 79-47 DS 3-12, Permit No. 79-58 DS 3-13, Permit No. 79-71 DS 3-14, Permit No. 79-82 NGI #13, Permit No. 78-91 NGI #14, Permit No. 78-92 Dear Sir- Enclosed please find Completion Reports and Perforating Histories for the above-mentioned wells. Production information for these wells will be sent as soon as it is available. Very truly yours, P. A. VanDusen District Drilling Engineer Enclosures ARCO Oil and Gas Company is a Division of Ati;~nticRichfieidCompany Form P~7 SUBMIT IN DU~ .... ~TE* STATE OF ALASKA (See other In- structions on reverse side) el L AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: ~',=,.- ,----,~"~Lr---~ GAS ~ WELLI I DRY[---1 Other Gas Injection b. TYPE OF COMPLETION: NEW ~ WORK~ DEEP-I---] PLUG [-"-] DIFF. WELL~ OVER I I EN I I BACKI I RESER. I I Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.0. Box 360 Anchorage, AK 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* 5. APl NUMERICAL CODE 50-029-20348 LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #14 (22-1-11-14) .... 99510 t0. FIELD AND POOL, OR WILDCAT 6A(su rface 6'N & 816'E of SW cr Sec 1, TllN, R14E, UM At top prod, interval reported below 2093'S & 2549'E of NW cr Sec 1, TllN, R14E, UM At total depth 1911'S & 2575'W of NE cr Sec 1, TllN, R14E, UM 5/14/79 I 6/1/79 16/7/79(2/1 4/80 Derf'dl 18. TOTAL DEPTH, MD & TVD 19, PLUG BACK MD & 'I-VD 20: IF MUI'TIPLE CO.PL., 9515'MD 8515'TVD 9~TPMD 8474'TVD H°Ws~An~ie Prudhoe Ba Field Prudhoe Oi~ Pool 22. PRODUCING INTERVAL(S), OF THIS COMPLETION --TOP, BOTTOM, NAME (MD & TVD)* Top Sad]erochit 8984' MD 8041'TVD Base Sadlerochit 941 5' MD 8425'TVD 1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec l, TllN, R14E, UM 12. PERMIT NO. 78-92 ELEVATIONS (DF, RKB,R'T, GR, ETC)* 117. ELEV. CASINGHEAD I 4R' RKR 21. ROTARY TOOLS INTERVALS DHILLED BY CABLE TQOLS All 23. WAS DIRECTIONAL SURVEY MADE Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP, BHCS/GR, FDC/CNL/CCL/GR/CAL, RFT, CNL/GR/CCL 25. CASING SIZE WEIGHT, LB/FT. 20" 94# Welded 13-3/8" 9-5/8" 72# Butt 47# Butt CASING RECORD (Report all strings set in well) GRADE / DEPTH SET (MD) HOLE SIZE CEMENTING RECORD H-40 ~79' be]ow Gq 30" 277 sx Arcticset cmt L-80 J 27051 ~17-1/2" 7200 sx Arcticset cmt L-80& ~ 8437 ~12-1/4" 700 sx (;laSs G cmt s00-95/ I AMOUNT PULLED 26. SIZE TOP (MD) 8136' LINER RECORD t BOTTOM (MD) I SACKS CEMENT* 9510' 1425 sx 2 P I~IFORATIOI~S OPEN TO PRODUCTION 9~8~ -9404 . '9223'-9233' 9354'-9374' ~9203'-9223' :'9298'-9318' ~9168'-9188' · 9260'-9280' :~'9158'-9168' 9250'-9260' 30. DATE FIRST PRODUCTION 27. SCREEN (MD) TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) (Ir~terval, size and number) ~ 9112 ' -9122 ' ~' 9080' - 91 ~0' ~9044 ' -9064' :9016'-9036' ~i: i'9122' -9142' ~988'-9008' PRODUCTION IPRODUCTION METHOD (Flowing, gas lift, pumping~ize and type of pump) 11 8031' 8015' 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A I WELL STATUS (Producing or shut-In) N/A DATE OF TEST. HOURS TESTED CHOKE SIZE FLOW TUBING CASING PRESSURE CALCULATED PR ESS. 24-HOUR RATE 31. DISPOSITION OF GAS (Sold, used for fuel vented, etc.) I PROD'N FOR OIL--BBL. TEST PERIOD OIL-BBL. GAS-MCF. GAS--MCF. WATER-BBL. IGAS-OI L RATIO 1 iWATER-BB.L' I OIL GRAVITY-APl (CORR.) I I TEST WITNESSED BY 32. LIST OF ATTACHMENTS Perforatinq Hi story 33. I hereby certify that the foregoing ancLattached L.nformation is coynplete and correct as determined from all available records. SIGNED ~, ~ Z~~~~.~ TITLE D istrict'Drilling Engineer _ *(See instructions and Spaces for Additional Data on Reverse Side) DATE 3/14/80 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: 16' 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26' "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35. GEOLOGIC MARKERS WATER AND MUD .... NAME None MEAS. DEPTH TRUE VERT. DEPT Top Sadlerochit 8984' 8041' Base Sadlerochit 9415' 8425' 36.~ORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. None Perforating Hi story NGI #14 (22-1-11-14) API 50-029-20348, ADL 28302, Permit No. 78-92 Began perf operations @ 2330 hrs 1/31/80. Installed & tstd BOP's. Perf'd intervals 9384'-9404' 9354'-9374' 9298'-9318' 9260'-9280' 9250'-9260' 9223'-9233' 9203'- 9223', 9168'-9188', 9158'-9168', 9122'-9142', 9112'-9122' 9080'-9100', 9044'-9064', 9016'-9036', and 8988'-9008'. Ran HP press bomb. Instalied& tstd tree cap to 5000 psi. Released well @ 0400 hrs 2/14/80. NG! #14 5/5i./79 CNL/FDC Run 1 5" " " FDC Run 1 5" " " B{ICS Run ~ 5" ' " " 9IL R~ i 5" XGl f.~].4 5/31/79 RFT Run ] 5" a c'cacn~.d copy X. J. Sa]Cl_stz'o~?, ~,~o~. ut, Engi_nee:ring A~'{C:O (Iii an~l ()v:~ (;,.;~;~,:, ~nj K:]c,.e:;uct ~,"'e (,a. cd Ilo.l_c D.S. ~-4 5/10/79 Spinner; ~ /- ( l-ll ~.~,S. 6-9 ]_~/l)/79 F~uid Duns.ity X&T ¢'/ 14 5/5'[,/79 CNI, 1.k~n J 5" ~ .se sJ.gn and re'turn tl~e :,['[~tched col~y a.s ~'ec. c il)t K. J. ARCO Oil and Gas npany North Alaska ,Jistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 19, 1979 Mr. HoYle Hamilton State of Alaska Alaska Oil & Gas Conservati on Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 .,!; i"AT T "C Subject' N~Permit No. .~Permi t No Dear Mr. Hami 1 ton: 78-91 78-92 Enclosed please find a Sundry Notice outlining our plans for each of the .above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:jh Enclosures ARCO Oil and Gas Company is a Division of AllanticRichlieldCompany Form 1 0-403 REV, 1-10-73 Subml t "1 ntentlons" In Triplicate & *'Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) OIL E] GAS F--'] WELL WELL OTHER Gas Injection 2. NAME OF OPERATOR ARCO Oil and Gas Company. 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, AK 4. LOCATION OF WELL At surface 99510 606'N & 816'E of SW cr Sec l, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 51' RKB, 18' Pad Elevation (Gravel) 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20348 6. LEASE DESIGNATION ANDSERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME UNIT. FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #14 10. FIELD AND POOL, OR WILDCAT iPrudhoe Bay Field-Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec l, TllN, R14E, UM 12. PERMIT NO. 78-92 :~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT ll~ ~ )xt~X~[~t~ REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER S"UT-OFF : ,REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. ARCO Oil and Gas Company proposes to perforate selected intervals in the Sadlerochit between 8988' and 9404'MD. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wireline work. The well will be flowed to the flare pit for clean up and liquids will be burned in accordance with the Department of Environmental Conservation Burn Permit. The downhole safety valve will be installed and tested upon conclusion of the job. Estimated start is December 20, 1979. Subsequent Work Reported 16. I hereby certify that the foregoing is true and correct 11/19/79 TITLE riisfriCt. P~i!!ing Eng. ineerDATE {This,pace for State:se}_.: ~ APPROVED BY ~/ ~ CONDITIONS OF APPROVAL, IF See Instructions On Reverse Side J'-~orL, - ..... Ala~,~ ~stnct Post Oliice Anchora;e, Ala~ka 99510 Telephon? g97 277 5537 November 6, 1979. Reference: Enclosed are Open Hole Logs' for the following ARCO wells: ~./'NGZ '# 1~4 ~)5/29/79 BHCS ~un 1 2" & 5" WGI # 4 10/16/79 CNL~-FDC ~an 1 5" ,';' t, FI)C/GG ~Ltn 1 " '~' DIL ~¢tn 1 2" & 5" "? " BHCS 'Run 1 2" & WGI# 4 10/16/79 CPL gm 1 5" ~/~lease sign and return the attached copy as receipt K, J, Sahlstrom North .Engineering TP~&N~,~TTAL # 455 DtSTRIB[rI'ION North ( ~.o] o~.. Fx×on Drillin~ ' ~ , lob].~. Eng. Nanager Getty R & D Sohio GOO 10 - o, Marathon State o.[ Alaska Phillips D & 3I Chevron Fosl Oil;ce Box 360 Ancho~e, Alaska 99S10 Teleph ; 997 277 5637 August. 9, 1979 Reference' Enclosed are Open-Hole Logs for the :following ARCO wells' NGI-15 6/50/79 NGI-15 7/1/79 NGI-13 6/50/79 NGt-15 6/50/79 NGI-15 6/50/79 NGI-13 6/30/79 NGI-15 D.S. 12-1 6/27/79 D.S. 12-1 6/27/79 D.S. 12-1 6/27/79 D.S. !2-1 6/27/79 ..... ~:~S~- 1 6/27/79 NG~-14 5/51/79 p.s. 14-3 ll/Z /TS BNCS 2" & 5'.' CPL 5" FI)C 5" DL 2" '& 5" DIL 2"& 5" PJ,T 5" CNL/FDC 5" CNL/FDC 5" C?L 5" BHCS 2;' & 5" DIL .2" FDC 5" DIL 2" BHCS 2" BHCS 2" Please. s~n and return the attached copy as receit)t of data. ~/ Very truly yours, /9 ./-) /~,/- R, A. Bellinger North Engineering TRANSMITTAL It 257 DISTRIB[fI'ION North Geology t:xxon Drilling Hobil llng. Hanager Getty R & D Sohio Geology ~hrat}~on State o~ Alaska t~hJ. llips D & M .Chevron -. l), ,. Anchora(fia, Alcs',<a 99510 'l'o1,::'"-'~-~ne 997 277 553 / August I, 1979 Reference' t~h~closed are Magnetic Tapes for the following /d~CO wells' 5/50/79 r,'55450 5/30/79 ~.55033 Run 1 Please sign and return thc attached copy as receipt data. Very truly yours, R. A. Bellinger North Fmgineering TP~&k'SMITTAL # 245 1)IS'l'Id [2rl'l. ON North Ceolog)' Drilling I:.ng. Manager R & Ceo] ogy State of Alaska ~lob i ;t Cot t' y So]~io IXk~'ra t-l~o;~ Chevron Te!ephone g07277' July 25, 1979 Reference: Enclosed is a Report of Sub-Surface Directional Survc? for the following ARCO well: NGI 14 Magnetic ~lti-Shot 5/30/79 Please sign and return the attached copy as receipt data. Very truly yours, R. A. Bellinger North ~gineering TRAaNS~ITTAL # 237 DI ST l~J t~[JT I ON North Geology Drilling Eqg. Manager /C;eolo~y State~ of Alaska t'.2xxon YIob 5 l Cetty Sohio I'h i 11 Chev ton Post r ';'~SJox 33,3 f , Ancho~ ~;ge, A,asxn 9-.'35 I0 Te~ephon8 907 277 533';,' July 12, 1979 Reference' Enclosed are the Gyroscopic Directional Surveys for the following .ARGO wells' P.S. 7-14 ~ 6/27/79 D.S. 14-7~ 6-16-79 D.S. 13-4 ~' 6-17-79 D.S. i4-8~ 6-12-79 NG! A4'--/ 6-20-79 Sub -Surface Sub -Surface Pleasesign and return the attached copy as receipt of data. , . Very truly yours, R. A. Bellinger _ l co,'x,x '. . C (_) M M - -- ... ._. 2 iff' .tO _. .... ,' ~ i',..; ..... l ....~r 'OL '-' "? ,' -r Tr-C-- F/LF: TlCdNSMITTAL # 205 DISTRIBUI'ION North Geology Drilling Eng. Manager R&D Geology State of Alaska }}XXOI1 Mobil Getty Sob io blarathon Phil lips Chevron ARCO Oil and Ga~-:~Company Alaska Re, ~ Post Office Box 360 Anchorage, Alaska '99510 Telephone 907 277 5637 July lO, 1979 Mr. Hoyle H. Hamilton State of Alaska A1 aska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- DS 7-14, Permit No. 78-81 ~DS 14-8, Permit No. 78-67 <~_~i~"~"-~14~ Permit No 78-92 Dear Sir' Enclosed is a Completion Report along with the Drilling History and Gyroscopic Survey for the above-mentioned wells. VerY truly yours, P. A. VanDusen District Drilling Engineer PAV'cs Attachments RECEIVED JUL I ARCO Oil and Gas Company Is a Division of AtlanticRichfieldCompany Vorm P--7 SUBMIT IN L~x ~ ~ATE* · STATE OF ALASKA (Seeother tn- st Fuctions OB reverse side OIL AND GAS CONSERVATION COSMITTEE i i WE[k cOMpLEIIO~ OR RECOMP[EIIO~ REPORI A~D LOG* I~. TYPE OF WELL: on.,,.~ ~ ,aSwg[~ ~ ~a~ ~ Other aas In3ect~on b. TYPE OF COMPLE~ON: WELL OVER EN BACK RESVR. Other 2. NAME oF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, AK 99510 ~'. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 606'N & 816'E of S~/cr Sec 1, TllN, RI4E, UM At top prod. Interval reporte~elow 2093'S & 2549'E of NW cr Sec 1, TllN, R14E, UM At total depth 1911'5 & 2575'W of N~~cr Sec 1, TllN, R14E, UM 5. APl N~CAL CODE 50-029-20348 6. LEASE DIi~IGNATION AIXlD SERIAL NO. ADL 28302 : i7. IF INDI;~r, A_LLO'i~'EE OR TRIBE NA31g_E 8. UNIT,FA/AM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI' #1"4 (22-1 -11 -14) 0. ~mr~ ~'b POOL. Prudhoe Bay Pr,!dhno (lil Pool 11. SEC., T., R., M., (BOTTOM HOLe. OBJECTIVE) Sec l, Tl lN, R14E, UM 12. PER.MIT NO. 78-92 [ i ELEVATIONS 13. DATE SPUDDED 14. DATE T.D. RF_d~CHED [15. DATE CO,1ViP SUSP O~ ABAND. 16.' 5/14/79 6/1/79 [ 6/7/79 I~OW iVIANY* ROTARY TOOLS 9515'MD, 8515'TVD [9469'MD~ 8474'TVD [ Sinqle All 22. PRODUCING INTERVAL(S), O.F THIS C(>MPLETION--TO~, BOTTOM, NAME (MD AND TVD)* Top Sadlerochit 8984'MD 8041'TVD Base Sadlerochit 9415'MD 8425'TVD (DF, RK~,.xRT,~ GR, ~L'TC)*I17. ELEV. CASINGHEAD INTERVALS DRILLED BY CABI,E TO0 I.,.q 23. WAS DIRECTIONAL SUI~VEY MADE Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP, BHCS/GR,,FDC/CNL/CCL/GR/CAL, RFT, ~NL/GR/CCL 2.5. ~ CASING RECORD (Report all strings set in w~ll) CASING SIZE I %VEIGHT, LB/FT. ~ GP,~kDE ! DEPTH SET (1V/D) [ HOLE SIZE ] C'~%ILNTING RECOI-LD 20" t94'# Wel'ded[ H-40 i79' Bel'o~ G~ 30"j277 sx Arcticset cmt 13-3/8" 72# Butt / L-80 ,[ 2705", [17-1/2" 7200 sx Arcticset cmt 9-5/8" 47# Butt / L-80&! 8437'. 112-1/4" 700 sx Class G cmt I 15oo-951 ' I [ ,, , 27. TUBING RlgC OP~I) 26. LINER I~EC O~ ;4,Z~] '[ TOP (liD) [BOTTOM (liD)IsAct~s CmiE2~T* 28. PERFORATIONS OPF_2q TO PRODUCTIOlq (Interval. size and number) N/A S CRF_.EiN (MD) AMOUNT PULLED SIZE DEPTH SET (I~iD) [ PACI(EII SET (MD) 7" 8031 ' ,J 801 5' 29. ACID, si!eT, Fi~/kC'I URE, CE, MENT SQUEXZ~, ETC. D]ili~TIi iNTEIqVAL (MD) AMOUNt £~ND KIND DF MA'I'E?~IAL USED i PRODUCTION N/A . DATE 0r TI~ST, J~ouRs TEST~) 'Jc~tOXE SiZE JPI~OD'N FOR ~'~O'Wi TUBING ICASLNG PRESSU1R~ JCALCULAT1gD OIL--BBL. 3 . mSPOS~TIO~ Or ~aS (Bold, uoed .tot.fuel, vented, etc.) OIL--BBL. GAS--i'ViCF. W£JI'IgR~--BBL. J GAS-OIL R.~TIO I I I GAS---1VIC~. W/~B BL. J OIL GRAVITY-~I (CO~.) TEST WITNESSED BY 82. LIST OF ~TT~CHMENTS 9r~ll~n9 a~story, 6yroscopic Survey 33. I hereby certify that the fore~ot, ng and attached information is complete and correct as determined from alVavallable records SION~D ~~ :~~~// TITLE District Drilling Engineer ~.'rr Z/lOZ79 ~ *(See Instructions and Spaces I:or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correc! ,.,,,.ell completion report all types of lanJs and leases ,n Alaska. Item: 16: Indicate which elevation is used as reference (where riot other~se sk~o~ for depth r~easure- ments 9,ven ,ncther spaces on this for~ and ,n ar~y ~tt,]c Items 20, ~nd 22:: If this well is completed for separate [ar~'cJ:;cti3r] frot~ ?~oro t}~,)~ or~e ..r~terval zone (multiple completion), so state in item 20, and i~ ~te'~ ?g show th~ ~)~c;Jt;<.,:.~l i~t~r~aJ, or ~te:vaJs, top(s), bottom(s) and name (s) (if any) for only the interv,~ re~o, rted ~ ~te~ 30 $~br~,t a separate report (page) on this form, adequately identified, for each add~t~or~al ~r~te~ vaJ to be seperately prod~cer~, show- ing the a~itionaJ data pertinent to such ~nterval. Item26: "Sacks Cement": Attached supplemental records for th;s well ~houJJ show the details of any mul- tiple stage cementi~g and the location of the cementing tool. Item 28: Submit a separate completion re~rt on this form for each ~r~lerval to be separately produc~ (~e instruction for items 20 and 22 above) 34. SUh,1MAI't~' '~)1~' F'(){~.MA'I'I()N 'I'E~.~'I'.'.4 INt'I.UI)JN(: IN'I'bH{VAL 35 ~; ~G ic MA~R WAT~[ AND MUD None ...... Top Sadleroch~t 8984' 8041 ' Base Sadleroch~t 9415' 8425' , , ,, , , · ' afl. COI1E DATA, A'I'I'ACI[ BRIEP' ,D~RIPI~ONS AND' D E'rE~'FED ~one ..... , , , ,, ., NGI #14 Drilling History API 50-029-20348, ADL 28302, Permit No. 78-92 Spudded well @ 1030 hrs 5/14/79. Drld 17½" hole to ~.Z_4_Z'. RU & ran 13-3/8" csg w/shoe @ 2705'. Cmtd w/7200 sx Arcticset cmt. Installed & tstd pkoff. Did 60 sx top job. Drld shoe & 10' new hole. Tstd formation to 12.5 ppg equiv MW. Drld 12-1/4" hole to 9.~. RU & ran 9-5/8" csg w/shoe @ 8437'. Cmtd w/700 sx Class G cmt. Installed & tstd pkoff. :_D_w. Qs.qz 300 s.~ A.?cticset I cmt thru lower FO. Did Arctic Pack job thru upper FO. Drld cmt, shoe & 10' new hole. Tstd formation to 12.5 equiv MW. Drld 8N" hole to~...... Ran DIL/SP/BHCS/GR, FDC/CNL/ CCL/GR/CAL & RFT. Drld to 9~_468]. Ran 7" lnr w/shoe @ 9510', top @ 8136'. Cmtd w/425 sx Class G cmt. Tstd lnr. Displ mud w/wtr & wtr w/lO.8 CaC12. Ran gauge ring & junk bskt. Ran 7" compl assy w/shear sub @ 8031', pkr @ 8015'. Set BPV. Installed & tstd tree. Pulled BPV. Displ CaCle w/diesel. Set pkr. Pulled dummy SSSV. Ran CNL/GR/CCL. Ran & tstd SSSV. ~Began long term tbg tst. Released rig @ 1200 hrs 6/7/79. ~/._~ ~/~ ?~'~-]~. Eastman ~~ Whipstock A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TiONA L SURVEY Atlantic Richfield Company COMPANY NGI 14 WELL NAME Prudhoe Bay, Alaska JOB NUMBER A579 S0303 A579 S0232 LOCATI ON ' TYPE OF SURVEY Magnetic Multi Shot SURVEY BY Kevin Durling OFFICE ALAS KA iCO NGI-14 i'~IAGNETIC ~qULTi-$HOT SURVEY ' i6 JULY 79 . RECORD OF SURVEY AI.L CALCULATIONc PERFO~,i~ED BY I B ,NI ELECTROt"~IC cor;!PUTER TRUE ' DRIFT VERTIEAL SUB DRIFT TOTAL COORDINATES C L 0 S O R E S SEVERITY SECTION 'PTH A~,~oLF,'"- .,. DEPTH SEA DIREC DISTANCE AN(SLE DEG/iOOFT · DISTANCE' D M D F G. D M S 8.62 N~9.00E 7,82" 5 20,99::.E NT6'OOE : 6,~8~"5" 2:2,8~:E::]' 2~ E :0'~1~ ,. . . · ~656 1 0 2655.58 2607.58 N85.OOE 6.59 S ~741 1 0 2740.57 2692.57 N86.00E 6.48 S ~795 ! 30 2795.55 2747.55 N66.00E 6.20 S !889 3 0 2B88'48 28b0,48 ] N52.00E ] ~,32':'S ?982 5 0 2981.25] 2933,25 N33,00E 0,~ .N ~07 6 15 3073'80 3025~80 N2 ~168 6 30 3166.22 3118.22 N26.00E 17.72 24,63 E 25,50 S 75 1 7 E 0,265 26.11 E 26.91 $ 76 2 46 E 0.000 27.27 E Z7,97 $ 77 11 .33 E 0,909 ' E 34' 'N'89:]:(.i6;:~0 E ' 2'i58 43,6L E ~7.08 N ~7' 53 17' 'E 0,269 9.66 2 o, 3~,53 ~261 7 15 3258.56 3210.56 N25 ~354 9 45 3350.53 3302.53 N26 ~447 12 0 3441,85 3393,85 N26 3540 15 0.~ 3532,27 3484,27 N25 ~533 18 15 3621.37 3573.37 N27 ~72& 21 0 3708.96 3660.96 N27 ~819 24 30 3794.71 3746.71 N27 ~912 27 30 3878.29 3830,29 N26 .OOE 27.77 N 48.41 E 5b.81 N 60 9 .37 E 0.807 .OOE 40.17 N 54.32 E 67.57 N 53 31 2 E 2.68~ .OOE 75,5a N E 3,227 .ODE 99.44 N E 3.501 .ObE ' i27,'27' N 9-7,"20"'E .... 1'60';-15 N'~7-22 13 E ...... 2'957 · OOE 159.31 N 113.53 E 195.63 N 35 28 27 E 3.763 .OOE 195.79 N 131.72 E 235.93 N 33 55 49 E 3.234 50.51 04,07 i29.08 195,62 235,93 ~005 30 30 3959,62 3911,62 N27 ~098 31 15 4039,44 3991,44 N26 ~190 31 0 4118.20 4070,20 N27 · OOE 235,14 N ,OOE 278.8.5 N · OOE 321.41 N 151,83 E 173. i3 E 194,~4 E 280.74 N 32 ~4 25 E 3,235 328,22 N 3~ 50 5 E 0,857 375,60 N 31 9 37 E 0.398 327, 374.75 ~283 32 0 4197,49 4149.49 N2 ~376 32 0 4276.36 4228,36 N2 ~469 33 0 4354.79 4306.79 N2 7.OOE 364,70 N 216,40 8.00E 40B,41 N 239,16 8,00E 452,53 N 262,62 424.07 N 30 41 2 Pi 473.29 N 30 21 9 E 0.570 523.22 ~'.130 7 41 E 1.075 422,87 471,74 521.33 ~562 32 0 4433.23 4385.23 N2 ~655 33 15 4511.55 4463.55 N2 ~748 34 0 4588,99 4540,99 N2 9.00E 496.45 N 286:45 9.00E 540.30 N 310.77 9.()OE 585.34 N 335.74 573.17 N 29 59 10 E 1.1i7 570.98 623.30 N 29 54 24 E 1.344 620,84 674.79 N 29 50 15 E 0.806 672.06 g841 34 15 4665,98 4617,98 N2 ;934 34 30 4742,74 4694.74 N2 5027 35 15 4819.03 4771.03 N3 8.OOE 631.19 N 9.0OH 677,33 N O.OOE 723.62 N 360.63 411o.. 726,95 N 29 44 29 E 0.434 723,90 779,45 N 29 39 28 E 0,437 7-16,07 532.62 N 29 38 5~ ~ U.~2 ~29.00 :OMPLETION REPORT 16 JULY 79 ¢,RCO GAS AND OIL ,A,~NrTIC MULTI-SHOT--~-0T(VEy ?ADIUS OF CURVATURE METHOD ZOMPUTED FOR EASTHAN BY F OF COMPUTATIONS LINDSEY & ASSOCIATES WELL NG I ~ 14 F.'" S 'E'LE~ "48--F-T '" OF SURVE.Y RECORD . ALL CALCULATIONS PERFORMED BY I B M ELECTRbNI'd"'COMPUTEk TRUE ~EAS, DRIFT VERTICAL SUB . DRIFT )EPTlt ANGLE DEPTH SEA DIREC TOT, AL COORDIN'ATE. S C L..O S U R"..E'S DISTANCE ANGLE DOG LEG SEVERITY DEG/1OOF7 SECT . D I STANCE D M DEG. 0 O "0 :0,00 '..-48,00 N O'OOE 204 0 15 203,99 155,99 SS1,00W 298 0 15 297,99 249,99 S61,OOW O,15 ti 0'.32 W 0,07 S 0,66 W 0,34 S 0,96 W 0.6B S 1,47 W 1,30 S 1.54 W D M S 0.00 $ .0 0 OW 0.35 N 6~ 29 59 W O'66 S 83 29 53 W 1,03 S 70 15 49 w O,O00 0,123 0,046 0.114 '0,00 ']i -0',05: . -0,84 393 0 15 392,99 344,99 S36.00W 487 0 30 486.99 438.99 S77,00W 581 0 30 580.99 532.99 S64,0UE 675 0 45 675,98 627,98 524.00E 2,03 S 770 0 45 769.97 721.97 553.00E 2.98 S 864 0 45 863,97 815,97 565,00E 3,62 S 959 1 0 958,95 910,95 N72,00W 4.51 S 0,83 W 1,62 S 65 11 40 2,02 S 49 47 4 2.~0 S 22 22 23 0,266 1,003 O,263 0.400 0,167 0,07 W 0.97'E 2.98 $ 1 31 52 W 3.74 S 15 2 30 E 0,62 E 4.55 $ 7 50 23 E 0.259 -1,4G -1,95 ' . - 2 · 40 1053 1 0 1052.94 1004.94 S40.OOE 5.52 S 1147 1 30 1146.92 1098,92 S47.00E 7.01 S 0,06 W 1.34 E 5.52 S 0 38 12 W 2.0~5 7,14 S 10 53 32 E 0.532 -4.56 '4.97 1241 1 0 1240.89 1192.89 S88.00E 7.77 S 1336 0 45 1335,88 1287,88 S48.OOE 8.31S 1430 0 45 1429,88 1381',88 535.00E 9.23 S 3,20 E 4,52 E 5,33 E 8.41 S 22 22 53 E 0,532 9,40 S 28 32 42 E 0,263 10,66 S 30 1 27 E 0,181 -[ 3...: -4,'2i -4'50 1524 O 30 1523.87 1475.87 587.00E 9.71S 6.20 E 11.52 1619 1 0 1618.86 1570.86 S67.00E 9.99 S 7,40 E 1~.43 1713 1 0 1712.85 1664,85 569.00E 10.60 S 8,92 E 13.d6 1807 0 45 1806.84 1758.84 N36.00E 10.22 S 10.20 E 14.44 1901 1 0 1900.82 1852,82 S52,COE 9.69 S 11.46 E 15.01 1996 1 30 1995.80 1947.80 N82.0()W 8.38 S 11,64 E 14.35 S 32 33 36 E 0,266 S 36 33 14 E 0.525 S 40 5 30 E 0.037 S 44 57 4 E 0.266 S 49 47 38 E 0.267 S 54 ~5 i6 E 0.542 -4.39 -5,95 -'~.56 -2,52 . -1.36 -O,1S 2000 1 45 2089,76 2041,76 S77,00E 10,09 S 11,33 E 15,i7 S 48 21a4 1 45 2183.72 2135,72 N90,OOE 10,42 S 14.17 E 17,59 S 53 2270 1 30 2278,68 2230.68 N. 72.0oF~ lO.O0 S 16,82 E 19.57 S D9 17 25 E. 0.31t~ 40 32 E 0.~21 16 5 E O.zb5 58 42 E 0,233 -1.77 -0.aO _ RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER lEAS. DRIFT VERTICAL SUB DRIFT )EPTH ANGLE DEPTH SEA DIREC D M DEG, TOTAL COORDINATES 5306 37 0 5044.62 4996.6~ N30.OOE 865,76 N 5399 37 30 5118.65 5070,65 N31,OOE 914.27 N 5492 38 45 5191.81 5143,81 N31,OOE 963.48 N ¢ 5864 39 45 5478.33 5430.33 N31.OOE 1166.84 N C L 0 S U R E .5 SEVERITY SECTION. DISTANCE ANGLE DEG/iOOFT DISTANCE D M S ; .. .... 493.95 E 996.76 N 29 42 23 E 1.144 992.52 522.52 E 1053.05 N 29 44 55 E 0.669 1048.64 552,09 E 1110.45 N 29 48 48 E 1.344 1105.91 674.28 E 1847.65 N 30 1 20 E 1342.58 5956 39 45 5549.07 5501.07 6049 40 45 5620.05 5572.05 6142 40 632838 155835,05!5787,05! 6421 37 45 5908.34 5'8~'0.34 6514 37 45 5981.87 5933.87 6607 ~8 0 6055.28 6007.28 N35,00E 1216.15 N 706,31 E 1406.~9 N 30 fi 48 E 2.780 N36,00E 1265,08 N 741,21 E 1466,23 N 30 21 57 E 1.169 N~6'fiOE1408,75 E 1,095 N~6.ooE' 1454.92 N 879.76 E 17'0'0~23 N 31 9 37"E ...... 0,'5'74 N~7.00E 1500.69 N 913.62 E 1756.92 N 31 19 59 E 0.658 N37.00E 1546.29 N 947.98 E 1813.75 N 31 30 40 E 0.269 6700 38 30 6128.32 5080,32 N~7.00E !592,27 N 982,63 E 1871,07 N 31 ~0 47 E 0.53~ 1401.36 1~61.45 1659'16 1753.34 1~10.40 l~6T 6793 39 15 6200.72 '6152.72 N36.00E 1639.19 N !017.~5 E 1929.24 N 31 49 32 E 0.914 6886 39 30 6272,61 6224,61 N36,50E 1586,77 N 1052.24 E 1988.07 N B1 57 24 E 0.346 1985.27 6979 39 45 63a4.24 6296.24 N37,00E 1734,29 bi 1087,73 E 2047.18 N 32 5 43 E 0.347 7072 39 45 6415.74 6367.74 N~8.00E 1781.47 N 1123.93 E 2106.39 N 32 14 52 E 0.6~8 7165 40 0 6487.12 6439.12 N37.00E 1828.77 N 1160.22 E 2165.77 N 32 23 31 f 0.519 2044.56 2103.97 2163.53 7258 40 0 6558.35 6510.36 N37,00E 1876.52 N 1196'20 E 2225.~6 m 32 BO 57 E 0.000 7351 40 0 6629.60 6531.60 N37.OOE 1924,26 N 1232.18 E 2284.96 N 32 37 58 E 0.000 7444 37 0 6702.37 6654,37 NB7,00E 1970,49 N 1267,01 E 2342,68 N 32 44 27 E 3,226 2223,27 2283,02 2340,87 7537 34 15 6777.96 6729.96 N42.00E 2012.27 N 1301.46 E 2396.46 N 32 53 35 E 3.412 7630 32 0 6855.84 6807e84 N36.00E 2051.75 N 1333.42 E 2446.97 N 33 1 11 E 3.023 7722 31 0 6934.28 6886.23 N36.00E 2090.63 N 1361e68 E 2494.98 N 3~ 4 37 E 1.087 2394.85 2445.52 RCO NGI-14 MAGNETIC ,~ULTI-SHOT ,SURVEY dULY RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE DOG LEG EAS. DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES EPTH ANGLE DEPTH SEA DIREC D M DEG. C L 0 S U R E S SEVER!TY D I STANCE ANGLE DEG/iOOFT O M S SEC T I ON L~ I S TANC E · 1 7815 31 0 7014.00 6966.00 N37.0OE 212.9,14 N 390,17 7908 31 0 7093,72 7045.72 N38.00E 2167.14 N 1419.33 POOl 30 45 7173.54 7125.54 N38.00E 2204.74 N 1448.71 8094 30 30 7253.57 7205.57 N39.00E 2241.82 N 1478.20 8187 30 15 7333.80 7265.80 N40.OOE 2278.11N 1508.11 E 2542,79 N 33 8 29 E 0,554 E 2590,56 N 33 13 19 E 0.554 E 2638.12 N 33 18 3'0 E 0,269 E 2685.30 N 33 23 59 E 0.386 E 2732.07 N 33 30 16 E 0.383 2541.46 2589.: .... 2~84.26 2731,14 .5280 30 0 7q14'24 7366.24 N4.0.OUE 2313,'86"N 1538.1! E 2778.45 N 33 36 48 E 0,259 8373 30 0 749q.78 7445.78 H41.OOE 23~9,.22 N 1568,31 E 2824,62 N 33 43 35 E 0.538 8452 29 45 7563.28 7515.28 Nfll.OOE 2378.92 N 159'4"1'3 E 2863.65 N 33 49 34 E 0.31~ 2'?'17.6~ · 2823,92 . 2863.06'.::: 8545 29 15 7644,22 7596.22 N42.00E 2413,22 N 1624.47 E 8633 28 30 7725.66 7677.66 N42.00E 2446.59 N 1654.52 E 8731 23 0 7807.58 7759,58 N42.00E 2479,30 N 1683.98 E 2909.05 N 33 56 48 E 0.596 2953.52 N 34 4 7 E 0.806 2997.12 N 34 11 5 E 0.538 R324 27 0 7890,07 7842.07 N42,00L ~039.67 N 34 !7 4~'--E 1~0"75 8915 26 45 7972.14 7924.14 N43.00E ~080.84 N 34 24 19 E 0.35© 9 ~ ~,.9 27 0 8055.09 8007.09 N42.OOE 3122.47 N 34 30 50 E 0.348 9102 27 0 8137.96 8089.96 N41.00E 2804.49 N 1797.19 E '3'1'64.3'8' N-~4 36 2'5"'E 0.488 91~5 27 45 8220.54 8172.54 rq41,0OE 2636.77 N '1825.24 E 3206.88 N 34 41 31 E 0.806 92~8 27 45 8302.85 8254.85 N42.00E 2669.20 N 1853.93 E 3249.88 N 34 46 57 E 0.501 9375 2~ 0 8379.75 8331.75 N41.00E 32.90.28 N 34..51' 55 E 0,383 ":' ' : ):!'" i! :' :'i ' ' :' ' · ' 2511,22 N 1712.7! E 2541.88 N 1740'.81 E 2572'87 N 1769.2:1 E 2908.56 2953,13 2996,82 ~u~9,~ 3164.30 3206.83 32~9.85 9515 29 0 g503.36 ~455.36 N41.00E 2749.27 N 1924.01 E 3355.63 N 34 59 7 E O.0OO 3355.63 HOLE CLOSURE 3355.63 ·FEET AT l"i 34 59 . 7 ,:E · · .. ARCO !~.AGNETIC F!ULTI-SHOT SURVEY OTHER DATA FOR EVERY EVEN- 100 FEET OF SOB SEA DEPTH, 16 JULY 79 TRUE ;.~EASURED DiPTH VERTICAL SUB HD-TVD DEPTH SEA DIFFERENCE VERT I CAL CORRECTION TOTAL COORDINATE5 148 24 8 148. 100 0 248, 200 0 0,14 N 0,15 E 0,03 N 0,47 W 348 44~ 548 648 348, 448, 548, 300 0 400 0 500 0 0 0,20 S 0,83 W 0 . 0,55 S 1,19 W O 1,0'8 $ · 1,71 W 648, 600 0 0 1,74 S 1,02 W 748 848 748, 700 0 848, 800 0 0 2,80 S 0,29 W 0 ~.52 S 0,78 E ::: 1148- 948, 900 l°o° 0 1248 1248. 1200 0 1348 1348, 1300 0 . : ::. ::::::::::. 7'0 s:: ~ ~ 0 7,78 S ~,32 E 0 8,41 S 4,63 E 1448 1448, 1400 0 0 9.40 S 5,48 15~.~ 1~4~. 1~00 · 0 g ~ ~4 ~ ~ 8 o ,' I:~..S:. · · 17~ 'IT,S':': 700 :: io' : '' 1848 1~48, 1800 --0--. 0 9,8~ 194e 1948. 1900 0 0 10,~5 ~ ~1~96 E 204~ 2048, 2000 0 0 9.20 2148. 0 2448 2548 2648 264 ~.: 2748 2448. 2400 2548, 2500 8. 2600 2700 ' 2848':2800 :::i:: 2~ 2949 2948' :2900 3049 3048, 3000 3150 3148, 3100 3250 3248. 3200 0 8.10 S 20.66 E 0 6.96 $ 22.52 E 0 6,60 S 24.49 E 3453 5.93 N 37.95 E 15.86 N 42.71 E 26.52 N 47,82 E '39,72 N .'5~'!! E 3m4~,, 3300 3448 · 3 ~00 AP, CO :4CI-"14 t-,A&;'4ETIC MULTI-SI-~OT SURVEY I;'"4TERPO~.ATED TRUE VEF;TICAL DEPTHS, COGRE:'I:'qATES AND CLOSURES FOR GIVEN DEPTHS i6 JULY 79 TRUE CC, DE ;'.'IEASURED VERTICAL TOTAL CO0;4DINATES C L 0 NAME DEPTH DEPTH DISTANCE ANGLE SEA D M S TOP SAD 8984 8032,81 2564,47 N 1761,60 E BASE SAD 9415 8415,07 2713,83 N 1893,21 E 3111,23 N 34 29 10 E 7984.81 3308,95 I.~ 34 54 0 E 8367,07 ~.'~ASU~E~ DZPTH AND OTHER BATA FOR 100 F:'iT OF-SUb SEA DEPTH. ! ~__J UL c 'R TRUE VE'FT ICAL SUB ,'..~ D- T VD VERTICAL DEPTH SEA DiFFiRENCi CORt<E CT [ 0,',~ TOTAL CCORD [NATES 66 76 ~7 3648. 360'~ ~ 13 5 107.43 N 87.09 37~8. 3700 20 7 1~1.17 N 10~.28 3.~48. 3800 3'3 10 181.97 P 124.91 99 10 22 3948. 3900 43 13 229.~5 ~.i 148.65 ~048, ~OO0 50' 17 253.51N 41~8. 4100 76 16 337.48 N 202.53 4,6 57 4248. 4200 94 18 392.48 i'1 230.75 4348. 4300 112 18 448.64 N 260.55 4448. 4400 131 19 504.~5 N 290,84 469q 4819 4940 5062 5156 5316 4548, 4500 150 !9 · . 4648, .600 !71 . 2!~ 4748. · 4700 192 · 2I 620,28N N 741.2i N 421.95 804,44 N 457.76 867,85 N 495.16 4848. 4800 214 22 '4948. 4900 238 24 5048. 5000 262 24 5436 5695 5148' ~100 288 5248' 5200 ~ 3.~+e · 5300 347 582 595 508 621 5448. 5400 5548. 5500 5648. 5600 5746o 7oo 5948, 5900 376 29 1144.96 N 661,14 E 406 30 1215,11 N 705,59 E 438 32 1284.46 N 755.29 E · 468. 804,40 E 496 1416.75',N 851.72 E . E 659 672 685 6048. 6000 6148. 6100 6248, 6200 549 25 1541,74 N 944,56 E 577 28 1604.75 N 991,99 E 606 29 1670,47 N 1040.08 E 5984 7114 7244 6348' 6300 6448" 6aO0 · 6548. 6500 636 665 696 7375 7500 7621 6648. 6600 727 6748, 6700 752 6848. 6800 773 1802.73 N 1140,40 :E 31 i936,42 N 1241.34 E 25 1996.35 N 1287.59 E 21 2047.77 N 1330.51 E 7738 7 a5 5 5948,6900 7048'7000 790 8 07 1'7 2097,29 N 1366,5B E · : 214 . o N l OZ'Sz E ARCO I',l E, I - 14. !'4EASURED DEPTH AND OTHER DATA I',IAGNETIC MULT!-SHOT SURVEY FOR EVERY EVEN 100 FEET OF SUB SEA i'... 15 JULY 79 DEPTH. MEASURED DEPTH TRUE VERTICAL sUB MD-TVD VERTIEAL DEpTH SEA DiFFERENcE ~. · ... , 7971 7148. 7100 823 16 8087 7248, 7200 839 16 2192,64 N 1439,25 E 2239.06 N 1475,97 E 8203 7348, 7300 ' 855 8319 7448, 7~00 ~ 871 72' 8549 7648. 7600 901 B663 7748. 7700 915 ~777 784~. 7800 929 15 24 lq 24 14 24 14.67 N 1625,78 E 55.44 N 1662,49 E 95,11 N 1698,21 E 8889 7948, 7900 941 9001 8048, · 8000 953 9113 8148, 8100 965 9225 8248, 8200 978 ¸12 13 2647.63 N 183~.7~ E 9339 8348. 8300 991 9~52 8fl48. 8400 lOOZ~ 13 13 2686,97 N 1869,77 E 2726,94 N 1906,60 E 79 ~.,~TERPOt. ATED VA 1"" LL~$ FOR EVEN 1000 FEET OF MEASURED DEPTH, TRUE 1000 999. 951. 4.67 S 2000 1999. 1951, 8.37 S 99. 29 1.79 N 7000 6360. 6312. 1745.00 8000 71'/2. 7124. 2204.34 oO00 8047. 7999. 2569.84 0,03 W 11,54 E 35,61 E 1095,8B E 1448.39 E 1766.47 E 000~ oo~ C] A..L 3~J~ N~OHS SH.Ld3O -I-1~' 00~9 0009 O09g ooe9 oo z.z 009./ ,cjic56:0~1 ,~:0c58: C]AJ. oo~ ooog 6./61 '91 ),']NP ,00~; =,,I 3-11/DS .3~NI~/AEIN:D _-I0 SNIO~'Et .LOHS IJ."ININ DI.LqNg~I61 St~9 ~8 ~10 0 m- 400 800 1200 1600 - 2000- 2400 - 2800- ~200 3600! 4OOO ARCO OIL & GAS WELL NGI-14 MAGNETIC MULTI SHOT RADIUS OF CURVATURE SCALE I" = I000' JULY 16, 1979 ii ALL DEPTHS SHOWN ARE TVD. 4~00 5200 560o 60~ 6400 6800 7200 7600 8000~ 8400.-~ TVD :8503' TMD=9515' 7 d ,3 ::'. :::7. ,_ .'] 1 .:": t ._.< i'" ? U I L !": 1 ¢': 1 LOC/:" .t i C[,: c:.;,[j i," L:'.'NY r.:..:: ::: :' ,. ,':':: ~ TD depths are taken from Carla Lenz with Arco Oil & Oas. Enclosed please find all field data sheets with film records. Also a complete print out of Gyro Drift, Intergimbal error and Radius of Curvature calculations. 27 JUNE 79 K B ELEV t~R FT F~ECOF~D OF SURVEY ALL C^LCULATION~ PFRFORf,!~D BY I B ~,~ EL[CTPONIC CO.~.-',PUTER StIR D~ ! F T 52,00 N 252,00 352,00 A~2,00 N O,OOE 552,00 q 0,0~ 6~2,00 752e00 h O,OOE fl52,00 t~ O~2.O0 N c,OOE 12,": 9 "~ ,'1 1200,09 l152eO0 ~! OeOOE 130o ,~ ,~ 1 ar)r".n.9 1252,00 lr, O0 n 15 159a.oo 1551,g9 17oe~ '~ 20 1~99,g9 1651,99 N17,OOE lqO0 '~ r) 17o9.00 1751.99 t..: 1~9r) 1 0 ]~qgeg9 lPSleg~ f',i2o. O0[ 2192 1 3q 2099,~2 2051,92 tlGg.00E 22hr) ] 0 21~,~0 2151oBg TOTAL COORDINATF5 0,00 0,00 O,O0 0,00 0,00 O,OO 0,00 0,00 0,00 0,00 0,00 0.00 O,OO 0,00 0,00 0,21 1,25 2e09 3,89 5,26 O,O0 W 0,00 W 0,00 W 0,00 W 0,00 W, O,OO W 0,00 W O,OO W 0,00 W 0,00 W O,O0 W 0,00 W 0,00 W OeO0 W O,O0 W O.O0 W O,Oa E 0,25 E 0,.~2 E O,St~ E 2,10 E ~,57 E 6,56 E ~., 7~. F 10,.~0 E CLOSURES O I $ T A ~'~iC E ANGLE O M $ DOG LEG SEVERITY SECTION ) D£G/IOOFT DISTANCE 0,000 0,00 0,000 O,OO 0,000 0,00 O,OOO 0,00 0,000 0,00 0,000 0,00 0,000 0,00 0,000 0-00 0.000 0.00 O,O00 0,00 O*O00 0,00 0,000 0,00 0,000 O,C ) 0.000 0*0~ 0.090 0.00 0,000 OeO0 0,250 0,83 0,500 1,22 1.000 2*03 0,7~0 4,40 0e250 6m92 0,500 8,78 1,000 11,19 O,SO0 14,21 ~FCOPD OF SU~V['Y ^LL C^LCt~LATION5 ~E~FOP~[D nY ! ~ ~ ELECTRONIC COHPUTE~ SEA DIr~E¢ 2~0r) 1 0 2579.77 2551,77 C.t~2.00E 27on I 30 2609.7~ 2651.75 N~5,OOE 2800 I ~ 2799.72 2751,72 N45.0OE 3000 q O ?99g.~0 2951.~0 N25,OOE ~1~o ~ O ~09B,O~ ~0B0,9~ N29,0OE 3~O'~ 1o ~0 3396.3~ 33~8,3~ N28.006 36~0 37o0 3~CO 2~ O 377~.P5 3730.B5 N27,50E ~OnO 3{) O 3961,0A 3913.0~ N27,0OE AIO0 31 {~ &0~7.20 3999e~0 N28.O0~ 6209 31 15 A137.~1 ~O8A,8! ~27.75E &300 31 O ~21~.~1 ~170.~1 a~8,SOE ~nO 3? O ~303.67 4255,67 N30.OOF 4BOO 3~ 0 ~63~.16 ~590,16 N3OeOOE 51OO 3~ 0 ~885.15 ~R37,1~ N29,00£ 5200 3~ 0 AOA6.56 ~918.56 N30,OOE ~3PO 3~ ~5 50~7,07 ~999e07 N31,OOF ?OTAL COORDINATES 11.62 N 12.05 12.9a N 13,13 16,26 N 16,33 25.2~ N 22,0~ 33,77 N 26,39 &3cO6 N 31.18 ~4,13 N ~6.28 136.9~ N 78,10 169,88 N 95,07 203,82 N 112,7~ 242,76 N 132.79 287.78 N 156.2~ 3~3,47 N 180,~0 ~2~,65 N 230.29 471.02 N ~57.06 51~,26 N 2P3.79 615,~2 N 33R.26 66~.3~ N 365.89 713.80 N 393.87 763.72 N ~22.11 81~,26 N ~50,71 $65,36 ~ ~fl0,81 CLOSURES DI STANCE ANGLE D ~ 5 1~.7~ N ~6 Z 21E 16,~7 N ~5 19 ~6 E 20.65 N 45 8 11E 26e7~ N ~ 16 35 E 33,51N 41 8 ? E 42.86 N 38 O Z% E 53,17 N 39 ~ 13 E 65e17 N 33 49 51E 81.12 N 32 17 3 E lOl,~O . 31 10 28 £ 126,37 N 30 16 27 £ 157.65 N 29 41 55 £ 19~,67 N 29 1~ 58 E 232,92 N 28 56 53 E 27~.71N 28 aO a6 E 327,~5 N 28 29 aT E 379.1~ N 28 2~ 42 E ~3u.83 N 28 ~2 38 E ~83.O7 N ~ ~8 18 E ~36.60 N 28 37 27 E 590.88 N 28 ~2 17 E ?O~,3~ ~ 28 47 29 E 758.~4 N 28 50 38 E 81~,Y6 N 28 53 22 E fi72.61N 28 55 47 E 9~0.68 N 28 57 55 E 989.96 N 29 3 26 E DOG LEG SEVERITY DEG/IOOFT SECTION DISTANCE 0,500 16.39 .) 0.122 18.1] O,50O 2o~z8 0,250 22,6~ 1,750 26,33 2,001 3~,27 1,001 42,77 0.366 53.15 Z.000 65.I6 2.50~ 81.07 2,503 101.2~ ~,005 126.06 ~*~01 1~?.15 2,~O1 193.92 1,000 231.93 8,001 275,~0 1,0~5 }25,80 0,~20 428.5~ 0.790 53~,01 0,~88 588,10 1,250 O,400 699.15 O,kO~ 755,05 O.e19 811.6~ O,57~ 86B,8" 1,0~8 926.71 GYROSCOPic St, JRVEY 27 ,jUNE 7g nECORD OF' SURVEY ^LL C~.LCULATIONS PERFOR~,qED ~'.~Y I B M ELECTRONIC COHPUTER D£PTH A~,LE DEPTH SUB DP ! FT DEG, TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M 5~00 ~7 ~O 5126,~O 5078,80 N31,OOE 917,09 N 550~ )8 30 5205,60 5157,~0 N)~,oOE 969,~9 N 5690 ~0 0 52~,0~ 5~)5,0~ N~0,50[ 10~,~7 N ~700 ~ ~O 5~59,93 5~11,9~ N~I,OOE 1078,6~ N ~800 ~9 g 5~7,~6 5389,36 N~2,00E 11~2,57 N 5900 39 30 551~,~0 566~,B0 N~,OOE 1185,9~ N 6200 ]~ 30 ~7~5,18 5697,1~ N]TeOOE 1~&2,0~ N ~nn ~9 0 ~,~1 5774,61 N~7,00E 1392,~G N ~11.B9 E 609,B7 £ ~O0 ~7 ~9 5901,1~ 5~B~,14 N~8,00E 1441,67 ~ 8G~,aZ 69~0 3~ 0 ~980,21 5932,21 N~T,OO~ 1A90,24 N 901,69 1050,28 N ~9 10 ~ £ 1111,~0 N 29 17 5Z E 1175,0~ N Z9 2~ lO E 1~a,95 N 29 ~8 ZI E i~02,19 N ~9 ~ 15 £ 1365,~ N 29 42 ~4 E 1~29,10 N Z9 ~ 15 E 1~9~,04 N ~O 10 55 E 1~1~,~ N ~0 ~1 &~ ~ 1~$0,97 ~ ~0 5~ ~8 E 6600 3B O 6059,01 6011,01 N37,50£ 1539,25 N 67,)0 ~m 0 6137,92 6089,B2 N~B,OOE 1587,93 H 976,65 6~00 ~9 0 ~.216.07 616B,07 N3B.OOE 1636,98 N 1014,97 690~) ~9 30 629~,51 6245,51 N~8,00E 1686,84 N 1053,92 7000 60 O 6370,A0 69~2,A0 N37.SUE 1737,~0 N 109~.O7 7100 ~0 0 6~7.00 6~9~,00 N~7.DUE 17B~.~0 N 11~2.20 7200 %0 0 6523.61 $67D,61 N37,OOE IB~9,56 N 1171,11 73:30 &O ~0 6599,93 6551.9~ N~7.00E IR91,16 N 1209.99 ?riO0 3~ 3~ ~677.0~ 6629,09 N35,00~ 19~2,6~ N 12~?,t8 7SO0 35 15 5757,07 ~709,07 N~7,50E 1991,00 N 1~fl2,85 760~ 33 0 !~39,85 6791,85 N~6,00E 20~5,95 N 1~16,~2 7nC~} ~1 9 7009,91 6951,91 ND~,50E llll,Ol N 1~76,97 7900 ~I 9 70~5,~3 70&7.6~ N~5,00E 216&,3~ N 1~05,1t 8090 ~1 0 71R1,3~ ?I~D,~& N~6,OOE 2705,26 N 1~3~,2~ ~lCn 3f) 30 7267,~ 7119,~8 N3~,50E 2~8,01N 1a~,75 ~00 30 C 7353.~'.7 7305,67 N~.O0~ 2286,63 N 1&95,53 1003,03 N 31Z~ 0 E I~6~,2~ N 31 ~ 36 E lOfl~,0~ N 31 59 4B E 2116.66 N ~2 Z0 14 ~ 2180.71N 32 28 54 E 2245,1~ N ~2 $6 42 E 2~0~.62 N ]2 ~2 18 E 236B,50 N 32 47 41E 24~4,~7 ~ ~ 5~ 10 E 2477,TT N 32 56 32 E 2529,~2 N 32 ~8 46 E 2632,56 N 33 ~ 48 E 26B~.65 ~ 33 6 18 ~ 2733.9& N 33 9 ~6 E DOG LEG SEVER 1 TY SEC T 1 oN DEG/IOOFT DISTANCE 0,750 1046,1~ 1,07~ 1107,6~ 1,62~ 1170,81 0,~39 1Z34,64 0,6~ 1~97,8~ 0,6~ 1361,07 1,3~7 1425,O1 t),O00 1489,26 0,6~} 155~,15 1,54~ 1678,16 0,6~7 1739,18 1,000 19~,~ 0,500 1987,47 0,541 Z051.~9 O,500 I,B2~ 2~77,1~ 0,517 25Z8,99 0,25B 2580,&9 0.6~2 26B~,11 A~C,'I DS qGl-14 GYROSCOPIC SURVEY 27 ,JUNE 79 RECOr~D OF SURVEY ALL CALCULATIONS PERFORHED P,Y ! B ~ ELECTPONIC COP. PUTER ~/'FAS. DF,',IFT VKPTICAL SuB DRIFT SEA DIREC DE'G, TOTAL COORDINATES 83oo 'JO r). ?~Oo77 739.~,~7 N~8,00E 232fl.03 N 152~.31 E ~)0 30 9 7~6,~7 7~7~,~7 N~7,~0E 2367.57 N 15~6,92 E 8~00 2~ 30 7613e69 756~e69 N~SeOOE 2406eB0 N J587.~0 E 8600 ~9 0 7700,9~ 7652,9~ N~le00E ~,~0 N 161B.38 ~ ~?OO 29 0 77~B,~+0 7740.A0 N3~,OOE 2481.64 N 1&~9.5~ E 9Og0 27 0 ~055.06 ~007.06 N42,OOE ~586e78 N 1737e98 E 9lO0 27 O Pl~,l+.la ~096e16 Nile0OE 2620,78 H 1768e07 E '~9~C~a 25 ~0 8f172e6~ 842Ae66 N40.OO~ 2749e~6 N 1872.6~ E POTTO~~ t~OLF CLOStJ~[ 3326.53 FEET AT N 3~ 15 3¢ [ CLOSURES DISTANCE ANGLE O M S 2783.77 N 33 14 59 E 2B33.62 N 33 19 44 E ~fi83.09 N 33 24 18 E 2931.68 N 33 30 23 E 2979.85 N ~ 36 k3 E 3026,70 N 33 ~2 ~0 E 3071.63 N 33 48 12 E ~161..2 N ~ 0 17 E 3206e96 N ~ 5 25 E 3253,38 N ~ 9 12 E 3286.75 N 3. 11 ~1 E 3297,38 N 3~ 12 47 E 3326.53 N 34 1~ 34 E DOG LEG SEVER l TY DEG/iOOFT 0.000 0.250 0.~ 1,~ 0.86,~ 0.970 1,800 0.849 0e6~7 0,~46 4,007 2.000 0.631J SECTION DISTANCE 2882.77 ~931.43 2979.66 3025.56 3071,54 3110o05 3161.~9 3206.94 ~253,38 At, CO DS HGI-I& GYROSCOPIC SU,~VEY 2T JUNE ?9. INTffRPOLATffD T~Uff VffRTICAL DEPTHSt COORDINATES AND CLOSURES FOff GIVEN DEPTHS COO~ ~.~A~F T~U~ \~EASURED VERTICAL TOTAL COORDINATe5 C L 0 $ U R E DFPTH D~PTH DISTANCE ANGLE D M $ SUB SEA ~10~,22 N 33 52 4~ E 7992.80 ~303,B1 N ~ 13 21 E A376,8~ 3347,04 N 3A ~0 ~B E 8~66,58 /tR¢O DS N~I-i~ GYm*SC*PIe SURV£Y 27 JUN[ 79 'IF;A%tlRED DF. PT~! A~D OTH.F.P DATA FOI:~ [.'VERY EVEN IOO FEET OF SUB SFA DEPTH, TRUE ?.FA SU~[:~ VERTICAL SUB MD-TvD V£t~T l CAL OE" T!,I DEPTH SEA D iFFERF..t~CE CORRECTION TOTAL COORDINATES t~e 1~8, 100 0 0 0oO0 ~ 2~, 200 0 0 C,O0 ~ 3~fl, ~00 0 0 o,00 $ OeO0 ~ ~aS, 500 0 0 0,00 $ 0,00 Aag 6~8o 600 0 0 0,00 748 7~8, 700 0 0 0,00 104~ 10a8, 1000 0 0 o,00 5 0,00 1~ ~148, 1~00 0 0 0,00 $ 0,00 ]2~B 1248, 1~00 0 0 0,00 $ 0000 l~4e l~e, 1~00 0 0 0,00 $ 0,00 1~4~ 1~48. 1500 0 n 0,05 N 0.00 164~ 164e, 1600 0 0 o,~5 N 0,1] 17~ l?~e. 1700 0 0 1,I] l~4e ln~, 1~00 0 o 1.45 N 0.~4 1~ 1~, 1~00 0 0 l.IO N 1,I0 ~O4e ~0~, 2000 0 0 4,66 N 3.28 ~145 ~148, 2100 0 0 5,70 N ~,6~ ~?~ ~74~. 2700 0 0 15.42 ~4~ ~45, ~00 0 0 17,30 N 17.27 2~4e 2gaS, 2900 O O 21,6~ N 20,17 3~4~ 30&R, 3000 0 0 29,25 N 23,99 314o 314~, ~100 1 1 3'~,2g N 2~,80 3?~n ~2~. ~200 % 0 &~.20 N 33.~& 3~1 ~3~, 3300 2 I 61,07 3453 34~8, S~00 4 2 77,64 ~ ~7.98 3~55 3548, 3500 ? 3 ~.62 N 5~.16 · . ARC,q DS NC~I-1/~ GYROSCOPIC SURVEY 27 JUNE 79 ~'EA$I~P. EP r~EOTH Ar,~D' OTHER DATA FOR EVFRY EVEN 100 FEET OF SUP SEA DEPTH, TRUF ~.!F'^SlJPFD VERTICAL SLtB HD-TVD VERTICAl., D~: o T!.l DEPTH SEA DIFFEP, ENCE CORRECTION TOTAL COORDINATES 366O ~6~8, 3600 11 ~ 12~,99 N 71,79 ~7~7 374~, 3700 1~ 7 158,52 N 89,10 3~?~ 3n~.~, ~00 27 9 195,5~ N 108,15 3q~5 3g~8, 3900 37 10 23~,~1N 129,29 alOl ~0~8, ~000 53 16 2fl~,20 N 156,~5 ~1.~ ~14~. ~100 70 17 3~1.67 N 18~,59 ~5~ ~3~8. ~300 10~ 18 ~I,B,6~ N 2~,15 ~57! ~8. ~00 123 19 50~,~8 N 276,11 ~691 ~5h8, 6500 1~3 20 562,27 N ~nl~ ~6a8, ~600 163 20 6~1,27 N 3.1,58 6033 ~7~8, &700 184 21 6~0,50 N 37~,91 5055 ~a~8, ~800 207 23 7~1,0~ N 409,41 5177 ~o~, ~900 ~29 12 802,57 N ~3,99 5301 50~8, 5000 253 2~ 865,87 N ~Bl,ll 5~27 51~. 5100 278 29 931,08 N 520.3~ 555k 57~8. 5~00 ~06 28 998,52 N 561,76 56~0 53a8. 5300 336 30 1070,03 N 60~,10 5nlt+ 5~8, 5~00 3~5 29 1139,88 N 6~7,21 59h3 ~8, 5500 395 30 120~,75 N 691,82 6073 56h8. 5600 625 30 1276.59 N 7~0,~2 6PO~ 57~8. 5700 ~56 31 13~3.88 N 790,06 6332 5fl~8. 5ilO0 ~8~ 28 1~0~,52 N 838,8& 6~5o 59a8, 5900 511 27 1170,19 N 886,~6 ~5~ fio~8, 6000 538 27 1532,53 N 933,55 6713 61/,8, 61, OO 56h 26 159A,2~ N 981,58 ~P~t ~?~. 6200 593 29 1657,36 N 1030.89 ~?1 63~8. 6300 62~ 29 1722.63 N 1081,53 ?Iai 6~8. 6~00 653 ~1 17~.91N 1132,59 723~ ~5~, 6500 683 30 1855.95 N 1183,16 7362 66~8, 6600 71~ 31 1923,17 N 1233,57 71. qO 6768. 6700 7~1 27 19P5,99 N 1278e76 7~10 aa~fe 6800 762 21 20hOe22 N 1319,51 772~ ~9~. 6900 780 18 2091,21N 1355,6~ ?~ah 70~o 7000 796 16 21~0,75 N 1389,72 GYROSCOPIC SUr~VEY 27 JUN~; 7;} DATA FOR F:.VE. RY EVEN 100 FEET OF ~UB SFA DEPTHe TRUF '.:'iCA SUF~ £ D vEr~TICAL SUB [)F~T~ I)EPTH ~D-TVD VERTICAL DIFFERENCE CORRECTION TOTAL 7~61 71~8. 7100 ~07q 77A8, 7~00 PlO3 73~, 7300 830q '7A~8, 7&O0 ~ 75~8, 7500 ~30 7668, 7600 865~ 7748e 7700 ~76~ 7~8, 7800 P~O 7~8, 7~00 ~gq~ ~0~8, 8000 ~10~ ,v1~8. 8100 9330 ~3~8e 8~00 9~61 p66~e 8400 81~ 17 2169 8~0 1'7 223"~ 861 1~ 2~31 876 15 2377 891 15 2~21 906 15 920 9~ 12 2~ 9~ 12 2~22 96~ 1~ 2661 082 1~ 2703 99~ 11 ,97 rl ,72 N ,77 N e44. N ~44 r~ .07 N · 9~ N N N 1~93,21 i529,06 1~99,2~ 1635~]0 1670,1~ i703,2~ 1735.57 1769.26 1802.]9 183~.96 1865,11 GYr~O$cOplc SUc~VEY I~,JTFPr~OLAT~'D VALI~[S FOr( EVEN 1000 FFET OF HL~'ASURED DEPTHe TRUF TOTAL COORO INATE$ 1~00 1000, 952, 0,00 $ 0,00 ~ ~O0. r~ 1999, 1951, ~,89 t~ ~,10 E ~000 2999, ~g~l, 25,2~ N ~,04 E GOOO 5591, ~5~3, 1238.63 N 717,~ E 7000 6370, 6372, 1737,57 N 1097,85 E 8000 71~1, 7133, ~2o6,26 N 1~3~,24 E 9qO0 ~055, 8007, ~6,78 N 17~7,98 E 27 JUNE 79 .. ..... ATLANTIC RICHFIEI. D._ COMPANy - '~_': ..... ~i..'~.'i'_'T_!-':'-. -'-' ......... ~ ................ i_' "' . ..... WELL. NGI 14 ................. *~': ~:.',~i___~ , SCA~ l": lO00' _ .......................... "" ~ ........ ';":'i--" .... I ............ t ....................... JUNE ~.7,~ 1979 2000 - TVD: 8475' TMD = 9468 __ .. ~' ~:i '~:~.:'_.: TAL' VIEW ............................ .... .-'-. ...... i---: .... :"-:": =' J_-.!'~.~.~_':'~i.~'i~"~i:"' ATLANTIC RICHFIELD COMPANY ................................ WELL N(~! 14 : ' -- ' ......... .-i--,.-.--F-?"SCALE =IOOO ........ ? .... :'~ ....... ~ ...... : .............. ...... ~ '; ....... :'-;"-: ! .................. ~--':'-J ' : I" ' -' ~' ~''~ .... ] "' ' ' ............................ :~."l-~t-'F-:,__'~:_ -j : ' : ,JUNE :2'7', 19'79 :. .............. ~__:_.!_~...L i : ...... .,. ~ : ; .,., ~',, i' ~ ~ "'i ; ! , i-RADIUS OF CURVATURE--.',-!--~-:--- ........... i'. .... i'=-' q ..... .--:--:-"':--T-i '~F-7-T'~-: ....... ..... j--: ~ ....... ~- -t ......... ~-~-~ .... t'--~ .... . .... -1'~- ....... , · . , , , ' , · ~ , ~ ' . . YROSCOPIC~;SURVE¥ ..... l'-;-".'.'-ff"i .... ~'~ '~' ...... ~'-'; ..... ~-'-: .................. '-'J"- --" 'i ....... .. 'J : , I ' ' I' i, : I I I : ! . ' '- ........................ ~ ........ t-~'-="-': .......... ~ ..... 1 ....... ~-! ....... ......... ·" ~"' ~ . i ,~"~f t ' ' · , ' -',- ' J '- --, ....; .... J'-~' "T ....... = ..... ~ 'J -~::"-'{~"~' ..... t--; '---"t~'"-"J--r T "' i~..";-"~-'-~"'-i ..... ;" ....... J .... ~-="~ I'q'"~,'-~:- ............... ~' ~ .......... ; ' ' ' ' ;---~ ' '. . -..--' ---4' .... ' .......'.--. ~ '- ......~ ....... ~ .... ;- .... ' --~- . , '... !..:,.l 'Z ........ !_,_,_:... '._LL '--'..L~.-i-.--L.J-L-...L-L.-~-L---:-; .... i.'_._:. .... ' .!_L_; ..... ! .?_L_ .--t-:--:-.~. -! %:--'- ' - ' . '.-- · . ' i ' ~ - . : . i 7 . ;-i' ~ '-" : ~ ii, : i I .~ , ' , ' i . I ~ . . I : ' ' I ; ' : ; ~ ' , : · '. ' ; ' , . ! , . , J , ' ~ [ i : , . , t J2:, I ; i , ; j ~ i ' J I ; ! ', . : i 4~ . t : · . : ' · ' · - ..... :' ..... :' -. ....:; ':", .... :": ..... "I :--i .......... ; ..... F'=-~-F" ,"T,'T-"--i-:''~ -:";-.~ .... ;-';--:",J-[-~'-?"!q -'T':-'j ' ' I, , . , , ~ ...... ~ ~ i . ~ ~ i ' . !__' , , t ~ '.~...~', ...: t ' ! I ; ~;', ~ ' ~ ' ' I . ' ' ' ' ' , ~ ' '~ ~ ' ' ' ! : I ~ ' , . ~ : ; : : . , , i · . _..' ~-' j :.'-' !'-:':it:.:-"!-"_ ';I.': ;.: :!Lt;_~ Ti '.:'. '..: :-'-t_.-F_L-.L-. r:".-~.i--:'i-F:.:i:'~.'-.~ ;i;i~?_;::_~.:;t-_:,.-_';:':t'~-',_.-.! ~:-'_';:~:: :';-!_F~:..:: · ' ':' ' ': ": i ' ]: !' .; ~_: :__..L'' .... J _L... =. ~ ,,...'.._ !_..~._.F., ._~..,,.__!._i_..j__!._!.. i__;..[- i ...!' ,.U I i:. J: ._;. F~__]_,.. j._i_.i .i ..:' ~.. I .i_.' __ :_..i_ +..{ .q_.'.~_.i. '... I - ' : . . .. : . , j · I : i : !~ .. , ......... [ i ~ ' ""Tq,' i ; :' :-',-'-_---?_; , '- .......... j .......... ,_ -. ;..:_.: ....... .. ...... i ~" ~-'" -:" -i ............. j ..... ...... I ..... . -' " I ' J ~.. .... ~ ............ : .................. , ........ I'-;-,.'-'~-'t--i-', ....... J ........ ·-I ....... i ...... I-': ..... : ......... i ........... ................. I.~i , .................. , ........... . ........ t__. _'._~ .......... ~ . ' .'TVD=8473~ : , .... . !- · :', ..... : .-i ~, i'-'T--;--"i'~"'---'Z'-, "-' ' °"'~"":~ ",-'J',-: :"J :-, "'-!-" ,--, :';' '-~ '? ' - ' '. ' ...................... 1'-'~ . =.,. ;-~-t'-- ..... ." ~' ' '"~ ,""" t' . . ~'- ," ....... .... . i ¥ ~ ...... T ~ ~ -'- ,"'~'--, ............. : I . ' I , . J ' ' : I ~ ', ~ J ' . ' 'J L ~ I /J"~-' ' { i ' ; ' i , ! 1- :'{ :. I .':-i'-:' .... :'-. l': ......... ~ ....... ;'1 ....... :""T-'~-''i'-'~ ..... //--~-F'F'/-'7-:'¥-'F'-i-:"'i-'T"!-F7'?-~'",";":-':-' '-t ....... ":~ ............ . 1' ' . : ~ ; ! ' ! ' : , : ' J ~ ' , i ; ' ;--'," J'~ t ~ , ; I ', : ' ~ I :' ' I , : · - ' .-' .... ~ ....~ ...... '---~--:--~---'~-t ..... ~.-.:.:-'. -.')'~./,~'~-~-.i-~. ~ -,-:..' .... :.= .... LZ...:....: .... . · { I J, ', I ......... ' ........ · ............... I ................. .~ ............... . ~ ....... ,--. .... .'- , , t ............. . . . ......... . ,. . , .... ,. ..... . ,.. . . ............ ,--7--.,--~-~--:-~-~-.-"-'--I-:,~-"~'~~".."'- .... ~' '~'/.~'~~-_~'-i: ;-!- ~q"'";---'"'=' ']"~~ . ".'-' ': ',: : :" '_!_F~_"-_l.'_;"!.-i~.:-i';~:.~::' :':'i_..:' ' //~~.-...',,L~L'i-":-~'' ..i'-':-l-.:-~:~-l: :..t:-.~F-~':-.~-~.".:i.: ....... .' ...... ~ ' ~ :~ "' : ................... i .... . i '' ~' ' ~ ' ~- J.. : .: ........: ..J.: ......... , ....... : . . · .......... ~...~_',_:_ ..= ..................... ..: .... : .... ... ._ . . __., . ....=_,. .................. ................ ;'-'~, t . ' ' , ,~'~"~/_~-~L~.~. ~ ' , ..... ~ ' ._;.' _ ~ ~ . , 1 '4,,,,"~ //~"',-~i"i i, ~ '., , I .................... : .................. ?-' .... T-" .... 4400",J../"--~ '-"'~----F-,"~.~".'"'r-"~-..--'-TI~-- .-~.'" --~ : ~ 'J' · ...... · ...... , . .: /7~F.?,,, ' , ! · , ' ', ..... : .... ; ..... ," ....... i .... 4m~,,/./ ~~-~-i ..... I ......... I-':'-: .... I.- ............ · . ..... ' ~" : .... ' .... LL..!-'~.~~'--i'L.:..!. ' ~ ' : . ~..'_-':'. :.i"~:-. 'L- ": _..~.~ '-.', -..'_-:'~ .:. :..:_~....! ....... : ..... J.:_: _'.:...: ........., ..... :':" ........... ' ............... i .... " ................ °1 ..................... ' I ............... ' ' !: '- .................. .~ ................ i .........! .......... I ~_ ..... ~ ~ ................... ; ............... ~ .............. ~____L. .... t ..... . I " ' .... ' ............................. , .......... i - ~ .~ ..... ............ ' ............... - ~ .................................. ! ..................... i-" . .................. ,. ....... ~ .... ' .... :.[ ..... L .: ............... '"': ....... " .... : ........ ~ ....... 1 ........................... .............................. t - . ALL ~EP'r.S $.0W~ .i_~_ _ .' . . .':i.'. i ..... , ~ ................ AEE TV.D .... !..:'.'- .... ' ......... .................................. ! ................... : ...... ' .... :-' .... ' :' -. ...... i--'-'. ...... :"- ~ ' I , :...: . : : ' -'i .... ~ ..................... .... [ '- .I ............................... "-T- ....... ~-'-T .................................... ARCO Oil an as Company Alaska h,:!4~on Post Office Box 3G0 Anchorag©. Alaska 9gfi10 Telephone 907 277 5637 June 6, 1979 Mr. Hoyle H. Hamilton State of Alaska Alaska Oil & Gas. Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 · 2 C--, i' (_)~. 3 3::©i_ / .~ f,, 1 T:C.:..L ,) EONF~:m ........ Subject' DS 7-14, Permit No. 78-81 Permit No. 78-67 Permit No 78-92 Dear Sir' Enclosed please find a Monthly Report of Drilling Operations for the above-mentioned wells. Very truly yOurs,/) ?. A. VanDusen District Drilling Engineer PAV 'cs Enclosures Form No. 10-404 REV. 3-1-70 :SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS O,L [] OAS []] Gas Injection WELL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage. Alaska 4. LOCATION OF WELL 9951 0 606'N & 816'E of SW cr Sec l, TllN, R14E, UM 5. APl NUMERICAL CODE 50-029-20348 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #14 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec l, TllN, R14E, UM 12. PERMIT NO. 78-92 Pool 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES 1N HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for the Month of May, 1979 Spudded well @ 1030 hrs 5/14/79. Drld 17½" hole to 2741'. RU & ran 13-3/8" csg w/shoe @ 2705'. Cmtd w/7200 sx Arcticset cmt. Installed & tstd pkoff. Did 60 sx top job. Drld shoe & 10' new hole. Tstd formation to 12.5 ppg equiv MW. Drld 12-1/4" hole to 9099'. RU & ran 9-5/8" csg w/shoe @ 8437'. Cmtd w/700 sx Class G cmt. Installed & tstd pkoff. Dwnsqz 300 sx Arcticset I cmt thru lower FO. Did Arctic Pack job thru ,, upper FO. Df~d~'~"Sho~ & 10' new hole. Tstd formation to 12.5 equiv MW. Drld 8½ hole to 9375. Ran DIL/BHCS/GR. As of May 31, running FDC/CNL/CCL/GR/CAL. 14. I hereby cl/l~[~that l~he fCrel~ing i~t~e and correct S,GNED /~~,~~,.~.~Z./T,TLE District Drillin9 En§r. DATE 6/1/79 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. ARCO Oil and Gas Company Alaska R¢o Post Office x 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 31, 1979 Mr. Hoyle Hamilton. State of A1 aska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, A1 aska 99501 Subject: Well Surveys at NGI Location Dear Mr. Hamilton' We have evaluated the planned well paths for NGI #13 and ~l~]~with reference to interceptions with all applicable existing we~llS. Adequate clearance has been planned at each interception point to safely drill the proposed wells. The existing well bores at NGI #5, NGI #10 and West Bay State #1 have been evaluated to determine the Ellipse of Certainty (EOC), considering the accuracy tolerance of the existing surVeys. The well currently being drilled at NGI #14 has crossed some ±950' vertically above the NGI #10 wellbore. After considering the accuracy tolerance of surveys for NGI #14, the minimum distance between the EOC for NGI' #14 and West Bay State #1 is +250'. The next.well to be drilled is NGI #13 which approaches three existing wellbores. Considering a typical EOC based on the accuracy tolerance of anticipated surveys for NG.I #13, the minimum distance planned between the EOC for NGI #13 and NGI #10 is ±184' The minimum distance planned between the EOC for NGI #13 and NGI #5 is +167'. NGI #13 is planned to be _+2300' vertically below NGI #4. To date complete reevaluations of NGI wells 1, 2, 3, 4, 5 and l0 have been completed. All surveys checked have been found to be within reading tolerance of human error; i.e., all hole inclination values are within ±No and bearing direction values are within ±3©. The reevaluation is continuing and all wells drilled at the NGI pad will be 'reviewed. A preliminary investigation indicates there will not be any conflict between the existing wells and the proposed wells for WGI. When the reevaluation is completed, a detailed ARCO Oil and Gas Company Is a Division of AtlanticRichfieldCompany Mr. Hoyl e Hamil ton May 31, 1979 Page 2 analysis will be conducted to determine the minimum distance between the existing E. OC for appropriate NGI wells and the EOC for proposed wells. A sketch of the NGI and WGI pads indicating the drilled or planned bottom hole locations is attached for quick reference. Also included are 1" = 50' plan views of the NGI pad showing the individual drilled well paths and planned well paths. A 1" = 50' plan view of part of the NGI #14 well path is shown which includes the West Bay State #1 well. Additional plan view sketches of the WGI wells will be sub- mitted .as they are completed. Sincerely, P. A.. VanDusen District Drilling Engineer PAV:CSA:cs Attachments cc: P. B. Norgaard w/Sketch I R. A. Crosky w/Sketch I L. M. Sellers w/Sketch I H. C. Heinze w/Sketch I. J. A. Rochon w/Sketch I GAS INJECTION WELLS BOTTOM HOLE LOCATIONS AS DRILLED OR PROPOSED NGI Locations WGI Locations West Bay State #1 / I / /2 Alaska Oil and Gas Conservation Commission }Ioyle H. Hamilton Chairman of the Commissior~Az~ Lonnie C. Smith Commissioner Harold R. Hawkins Petroleum Inspector May 21, 1979 To Witness BOP Test ARCO NGI No. 14 Sec 1, TllN, R14E, U~ Permit No. 78-92 M~Y..~6, 1979 - I left Anchorage by Wien Air to Prudhoe at 11:50 AM, arriving in Prudhoe 1:20 PM. Purpose of trip to witness BOP test on Parker Rig 141 on MGI Well no. 14. Ben Davis was the supervisor for ARCO and Tom Black was the rig pusher. When I arrived at the drill site, cementing was in progress. ~y.. 17, 1977 - Nippling up BOP's was finished at 8:30 P}i and testing was started at 9:00 PM. Annular preventer was tested ~o 3000 psi. The next tested was the upper pipe rams, the inside kill valve, the inside choke valve and the upper Kelly to 5000 psig. With the upper pipe rams still closed, the outside kill valve, the outside choke valve (HCR), and the lower Kelly was tested to 5000 psig. The kill valves were tested with check valve disabled. With the upper pipe rams still closed check valve on kill line and eight valves on the manifold and the super choke (Swaco) were tested separately to 5000 psig. The lower pipe rams failed to test. The lower pipe rams were found to have burrs on ram blocks and were ground off, and then satisfactorily retested to 5000 psig. The next test was a performance test on the accumulator. The master gauge read 2700 psig, the manifold pressure read 1500 psig, the annular pressure read 1000 psig. With the power supply shut off the upper pipe rams, lower pipe rams, and annular preventer, were closed, and the HCR valve was opened, all at one time, using the remote controls, The pressure on the master gauge dropped to 1250 psig and held steady. With the pumps turned back on the pressure rose to 1450 psig in forty-five seconds. This performance test indicated the accumulator precharge and the pumps were in good shape and there were no leaks. The nitrogen backup bottles had 1800, 1900, 1900, 1900 psig. The test stem was pulled out of test plug and the blind rams were tested last to 5000 psi. ~ere was a manual choke on the manifold that operated freely. There were ~wo drill stem safety valves on the floor which cbecked ok, one was a dart type and the other was a ball type. ~litness BOP Test ARCO MGI No. 14 2 May 21, 1979 The location in general was clean and free of debris. The pit was open but well bermed. There was a well sign up with all data ok. In Summary: I witnessed the blowout equipment tests for ARCO on NGI-14. ~en tests were completed, all BOP equipment and power sources operated and tested satisfactory. Drlg. Permit Opera tor__~ Satisfactory Type Inspection Yes No Item 0~) Location,General (~) () 0~) () (x) () (~) () () () () () Ala_..a Oil and Gas Conservation Commi~ e Field Inspection Report Wel 1/Platfm Sec/ Represented by~ D~d/9 Name & Number~/.~l~/ SatisFactory Type Inspection Yes No Item ~) BOPE Tests 1. Well Sign 2. General Housekeeping 3. Reserve Pit-~)open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data ( ) ( ) 7. Well Nos. , , , ( ) ( ) 8. Hrs. obser , , , (~) () (~) () (~) () (~) () () Cv) () () ~x) () 15 -" "' ./~Cas~ng set @~J 16. Td~t f'luid-~')wt~ )mud ( ) oil '17. Master Hyd. Control Sys.-~?~6 psig 18. N2 btls./~,~_,!?~.,~~si,q 19 Remote c°ntrois 20. Drilling spool-~~ "outlets 21. Kill Line-~) C~eck valve 22 Choke Flowline ~) HCR valve 23. Choke Manifold No. valvs~flgs/~ 24 Chokes-~)Remote( ~Pos.~Adj 25 Test Plug-~)Wellh ( )cs9( )none ( ) ( ) 9. BS&W , , ,-- (~ ( ) ( ) ( ) 10. Gr. Bbl~ ~ ~ , (~ ( ) 26. Annular Preventer,~sig ( ) Final Abandonment -- 0~) ( ) 27 Blind Rams,~_psi9 ( ) ( ) 11. P&A Marker ()l) ( ) 28. Pipe Rams~__psig ( ) ( ) 12. Water well-( )capped( )plugged (X) ( ) 29 Kelly & Kelly-cock.~ psig ( ) ( ) 13. Clean-up (~) ( ) 30. Lower Kelly valve,-mg~, psig ( ) ( ) 14. Pad leveled ~~ ~) ( ) ~31. Safety Floor valv~BV ~)Dart Total inspection observation time~~days Total number leaks and/or equip, failures / Remarks~~ ~. /~ ~ j ~A~m~ ~ ~ ~ B~'IF5 (x~) ~~ ~'~u~ ~' l'~~ o~Kj cc: _ or _ ARCO Oil and Gas~ompany Alaska Reg' Post Office L~OX 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May ll, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 I 3;:'I~:; ..- '~ STAT TrC t S'rAT Fit. F: SUBJECT:~ermit No. 78-91 ~ermit No 78-92 Dear Mr. Hamilton' Enclosed please find a Sundry Notice along with the as-built surveys outlining the correct surface locations for the above mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV 'cs Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldC'ompany Form 10-403 REV. 1-10-73 Submit "intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 5. APl NUMERICAL CODE 50-029-20348 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. O,L l--! CAS i--i WELL L--J WELL L--J OTHER Gas Injection 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360 Anchorage, Alaska 99510 NGI #14 4. LOCATION OF WELL - At su trace 606'N & 816'E of SW cr Sec 1, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 51 'RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec l, TllN, R14E, UM 12. PERMIT NO. 78-92 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTI PLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTEJ Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED oPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. The correct surface location for the NGI #14 well is 606'N & 816'E of SW cr Sec l, TllN, R14E, UM as shown on the enclosed as-built. The estimated loCation shown on the Permit to Drill should be changed to reflect the as-surveyed location. 16. I hereby certify that the foregoing is true and correct 5/11/79 · , TITLE District Drill.ing,Epginp~r DATE (This space for State~flC~e ~ :~ ~ K~ ? ~t CONDITIONS OF APPROVAL, IF ANY: See Instructions On Reverse Side 816' 840' 865' 890' 9t5' section 940_~' S E C T~ON 965' 989' i014' SECTION 12 1039 1064 ! 089 1114 LEGEND · EXISTING WELL OR CONDUCTOR PIPE NOTE: WELL NO. I TOP PAD ELEV. ,= 18.4 FT. ABOVE MLLW AS-BUILT~ REVISION No. 2_ ARCO AFE No.292265 HVL No. 30-NIS-75 CERTIFICATE OF .SURVEYOR I HEREBY CERTIFY. THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT · REPRESENTS A LOCATION SURVEY MADE BY ME OFf UNDER MY SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE_CO..gRECT. DEC 18, 1977 ADDED WELL 13 514 ,%, ~'¢i "~) 7-' /" ' · J- BUILT WELl NO. I LAT. 70°19'36.129'' LONG. 14.8°28'50.016" Y 5 q71 400.07 X 687 350.54 WELL NO. 2 .L A T. 70° 19' -57 284" LONG. 148°28'50,762'' Y 5 971 516.90 X 687 32206 WELL NO. 3 LAT. 70° t9'38.441" LONG. 148° 28'51.493'' Y 5 971 633.76 X 687 294.09 WELL NO. 4 LAT 70° 19'39.596" LONG. 148° 28'52.223" Y 5 971 750.62 x 687 266.18 WELL NO. 5 LAT 70° 19'40.749" LONG. 148028'52.947'' Y 5 971 ,867.11 X 687 258.47 WELL NO. 6 LAT. 70° :9' 41 908" LONG. 148° 28'53.682" Y 5 971 984.28 X 687 2/0.34 WELL__ N(.:. 7 LAT. 70'~' 19',4,3.052" LONG. ~48°28 54.412 Y 5 972 099.94 X 687 ! 82.47 WELL NO. 8 LAT. ';zO° i9'44 2i0" LONG. / 480Z8' 55.!26'' Y (~ :~72 2 ;7.07 X 687 55.06 WELL NO. 9 LAT. 70° 19' 45.370" LONG i48°28'55,850'' Y 5 972 334.31 X 687 I27.31 WELL NO. i© LAT. 70c 19' 46.5!9" L(.;, t:~; G. IqScL,~'St~.589'' 'r 5 t¢72 450.53 X (;87, D99.!4 WELL NO. II LAT. 70° 19' 47. 675" LONG,. ~ 48° 28'57, 3~9'' Y 5 972 567,37 X 687 071,18 WELL NO, 12 LAT. 70° 19' 48. 830" LONG. 148°28'58.044" WELL No. 13 LAT. 70° 19' 49,98~" LONG. 148028 58.774 WELL No. 14 LAT. 70° I 9'51.136" LONG. 148°28 59,492 Y 5 972 684. II X 687 043.43 Y 5 972 800.71 X 687 015.51 Y 5 972 917.24 X 686 ATLANTIC RICHFIELD CO. WELL t THUR 14 NORTH INJECTION SITE LOCATED IN PROTRACTED SECTIONS I 512~ T I,IN~ RI4E~ ,U,,.M. PREPARED BY HEWlTT V. LOUNSBURY 8 ASSOC. Z23 W. 6TH.AVE.-, ANCt-tORAGE, ALASKA DATE OCT 9~ 1975 SCALE I"-- 300' LOOSE CHKD. BY G. D, FIELD BK. LEAF c.onservation Prudhoe £~y Unit Atlantic ~ich~.,~lel~_ Company Permit ~o. 78-92 ~r. P. A. VanDusen District Drilling Engineer Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 Dear Sir: Enclosed is the approved application for permit to drill the above reference~ well at a location in Section 1, Township 1!~ Range I4~, .. .... ~?ell samples, core chips and a mud log are not required. dir~tion survey is requlre(~. ~any rivers in Alaska and their drainage systems have k~een classified as important for the spawnin~ or r~igration of anadromous fish. Operations in these areas are subject to AS 16.50.870 an¢~ the regulatations promulgated thereunder (Title 5, Alaska Ad~ministrative Coae). Prior to co~mencing opera- tions you may ~ contacted by the ~{abitat Coord. inator's office Department of Fish and Ga~e. Pollution of any waters of the Etate is ~rohil?ited l?~y Chapter 3, Article 7 and the regulations Fro~,u!agate~ there- ..... c- ~ Chapter 70) und. er (Title 18, Alaska Administrative .~ose, · the Federal Water P~l~ution Control Act, as amen~ed. Prior commencing operations you may ~e contacted, by a representa- tive of the Department of ~nvironmenta! Conservatiou. Pursuant to AS 3~ 40, Local . .~lre Under State Leases, the A. laska Department of Lair is being notifie~ of the issuance of this per~it to ~rl!! To aid us in scheduling field ~ork, %~e ,~,ould appreciate your Hr. P. A.VanDusen Prudhoe Bay Unit NGI No. 14 -2- p~.cember 7 1972 notifying this office within 48 hours after the well is sr.~udded. 'g~e v.~ould also like to be notified so that a r~presentative of the division may be present 1:o witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonmen.~., please give this office adequate advance notification so that we may have a witness present. Very truly yours, Hoyle H. ~ami!ton Alaska Oil & Gas Conservation Committee · ~ ~ '~ C,~t~TM v.~/o encl cc: Department of Fish and Game~ Department of Environmental Conservation w/e/encl. Depar~.~ent {r Labor; Supervisor, Labor Law Compliance Division w/o enc!. November 28, 1978 Mr. H°yle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' NGI #14 Dear Sir' Enclosed herewith is our Application for Permit to Drill NGI #X~ and a $100.00 filing fee. An As-built survey will be sent as soon as it is available. Very truly yours, l P. A. VanDusen District Drilling Engineer PAV'jh Enclosures Est. Form 10-401 REV. 1-1-71 la. TYPE OF WORK b. TYPE OF WELL SUBblIT IN TR' ~.TE (Other instruct, on reverse sid~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITYEE PERMIT TO DRILL OR DEEPEN DEEPEN [-'] DJvisi0Jl ~i' (!ii ~'..'~.~ ,:;::::~ '.:,:~urw.,: OTHER~5.~Y~erlO~I SINOLEzoNE r--] ,::~'~,;i,~U~I~T"LEzoNE r-] DRILL E~ OIL GAS 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL Atsurfa~e 605'N & 825'E of SW cr Sec. 1, T11N, R14E, UM At p,opo,, ,rod. zo,e 2000'S & 2680'W of NE cr Sec. 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 9 miles north of Deadhorse, Alaska 1, T11N, R14E, UM 50-029-20348 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #14 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Fi eld-Sadlerochit il. SEC..T.R.. M.. (BOTTO~ Pool HOLE OBJECTIVE) Sec. 1, TllN, R14E, UM 12. 14: BOND INFORMATION: ~E Statewi des~rety ~.d/or ~4o. 15, DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, ff any) 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 51' RKB Federal Insurance Co. #8011-38-40 2000' 1320' 16. No. OF ACRES IN LEASE 2560' 19. PROPOSED DEPTIt 8471'TVD (9485'MD) ,moun, $100,000 17.NO,ACRES ASSIGNED TO Tills WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START February 1, 1979 23. PROPOSED CASING AND CEblENTING PROGRAM SIZE bF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH "':" Quantity of cement . . . 32" 20" 94 H-40 80 250 sx PF II to surface 17-1/2" 13-3/8" 72 M~-80 270'0 Circ to surface - Approx 5500 sx 12-~/4" 9-5/8" 47 !80&95 ..8800 1000+ cmt. column on 1st stage pl 300 sx on 2nd stage. · 8-]/2" 7" 29 N-80 9485 Approx. 350 sx. US Atlantic Richfield Company proposes to directionally drill this well to ±9485'MD (±8471'TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be used. The BOP equipment will be pressure tested each week & operationally tested each trip. A string of 7" 29# N-80 tubing, packer & necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all.uncemented annuli within the permafrost interval. Selected intervals within the Sadlerochit will be perforated and reporte on a subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all Wireline work. The downhole safety valve will be installed and tested upon conclusion of the job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby certgy that the F~egoing is True and Correct DAT, , 3!/.22./78 ~TLE Dist..Drlg. Engr. (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] YES ~ so DIRECTIONAL SURVEY REQUIRED ~YES [] NO CONDITIONS OF APPROVAL, IF ANY: MUD LOG [] YES I~'.No OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE -¥5- o '~; - z. c PERMIT NO. APPOVED BY APPROVAL DATE *See Instruction On ReverSe Side December 7, 1978 DATE 1_2/7/'"(8 Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPEN. DIXi No 'special'effort has been made to chronologically organize this category of information. · . C.7.~CR L_L ..... ~_, NE~ WELL PE[L~.iTS Yes Ne Remnrks ! Is the 2. Is well. 't:o be located in a defined peel .............. 3. Is a regi,~i:c:re'd survey plat attached ................ 4 Is we]_l !"' ~ated prq~.~r dJ,.st~ce fr~ property line 5. Is well J_c,~ 'abed proper dist~xce from other wells .......... 6.. Is sufficient und~Klicat~t acreage avail~le in ~is 8 ~s oy)~rakor ~':e only a~ecked ~r~y · _ .... . 9. C~ ~m~.hh ~:~) approwx] ~ffore 'hen--day wait r~s o~rak~r h~ve ~ ~nd 5n force ................. !. is a conse~at, ion order needed ................... 2. Is aaY~kniserative approval needed ................. Item Approve Date -'(1) Fee ;?. '~! ~,~ ':~ i ,/ .3. Is conductor string provided .................... ~ _4. Is enough ~ment used to circulate on conductor and surface .... Will comen!_, tie in surface and intermediate or production strings Will cer~': ' cover all known productive horizons .......... . ~.'~.9~]: ..7. Will sur{, ua casing protect fresh water zones ........... ~_~:~ ......8Will all ~' ~sing gLve .... ade_quahe -~aF('ty in collapse, tension & burst. _9. D~,.s BO'gE "_a,.e sufficient press~e rating - Test ~o S'ooo psig 10. ~[as Di.F~i proved Pi~ o~ ~eratien ................ 'ddi hional Reel.' .kre~nts: -(5) BOPE ~ ~ ?' Apprc{~al Recom~..ended: C~.o! _ogy: Engineering: Revised 4/14/78 11 000000 11 000000 I 111 O0 O0 1111 O0 O0 11 O0 0000 11 O0 0000 I 1 O0 O0 O0 11 O0 O0 O0 I1 0000 O0 11 0000 O0 ,1"1 00 00 I i O0 O0 ! 11111 000000 I 11111 000000 060666 000000 666060 000000 66 O0 O0 60 O0 O0 68 O0 0000 ~ O0 0000 66b~O6bO O0 O0 O0 66666666 OO O0 O0 66 66 0000 O0 66 06 0000 O0 66 66 O0 O0 66 66 O0 O0 b~6666 O00OO0 666666 000000 777777'777'7 '777'7777777 77 77 77 77 7'1 77 '77 77 '77 77 77 77 000000 000000 00 00 00 00 00 0000 00 0000 00 00 00 00 00 00 0000 00 0000 00 00 00 00 00 000000 000000 000000 O00000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 OO O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 b6666~ 66 66o666~0 66 6~ bb66bb 66 7777 77'/777 7777777777 7'1 7'7 77 77 77 77 17 17 77 77 77 77 333333 333333 33 33 33 ,3] 33 33 33 33 33 33 33 3.3 333333 33~333 U U D D D D ii H U U D D H H U O O D H ii U ti D D H H H H H U O D D H H O U O D a H U O U O O D D D D H H OO0 EEEEE 1 0 0 g I1 O 0 E 1 0 O EEEE 1 U 0 E 1 O 0 g 1 OOO EEEEE 1 i 1 *START* USER PCAB [10707,600631 tqOi'4IT(]R 8~8 KLIOE,34 JLiL,-79' *STAPT* *START* USE14 PCAL [10707,600,163J. [4UNIT[JR 8w8 gLl. Og3q dUb-79..8 ART* J (,,lB SNIP SEQ. 81.41 DATE SHIP SEL-i 8141 I. Al, g 05-NAR-80 OS-NAR-80 14:28:54 14:28:54 I1 I 1 i1 1I ii I1 ii !I I I Ii II I I II II ii ii II I1 I..[ I,I 1 1 PPPPPPPP PPPPPPPP PP PP PP PP PP PP P P PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP TTTT TTTT ~'StAR I USER PCAb [10707,00063] dot3 SHiP MUNiT()R Sv~S ~.LlOE34 JUI.,-79. ,S~ARI FILB: DS~H:~HIP,TLJ<255>[10707,60063] CREATgD: FRIN~ED: 05-~AR-80 14:29:21 OUEUR S~iI'ChE8: /~16E:FOHT /COPIES:I /SPACiNG:I /Li~i'f:II.O /F'ORMS:NORMAL 8141 DAft. 05-P,~AR-80 05-~"iAR.., 80 09:17:53 14:28:54 ! PCCC 5. H IPP II',~G 1. N$:I'RUCTIEibI5 iSSUED 30-dt. Jl',i-79 17.'48 B x (;F..I~ PCCC VV VV VV VV VV VV VV VV VV VV VV vv VV vV VV VV llIlll [IIIIl il I1 I1 ]1 II 1I 1i Ii I1 11illi llIIii YY ¥¥ YY ¥¥ 000000 000000 5555555555 000000 OOO00O 5555555555 O0 O0 O0 O0 55 O0 O0 O0 O0 55 O0 0000 O0 0000 555555 O0 OOO0 O0 0000 555555 O0 O0 OO O0 O0 O0 55 O0 O0 O0 O0 O0 O0 55 0000 O0 0000 O0 55 0000 O0 0000 O0 55 O0 O0 O0 O0 55 55 O0 O0 O0 O0 55 55 000000 000000 555555 000000 000000 555555 *START* USER PCAb [10707 o0063] dOB SHiP NONITOR SwS KLlOE34 JUL-79' FILE: DS~HIVERiP"'~.O05<057>[,10707~60063] CREATED: PRiNI~ED: 05-MAR-8() 14:29:37 QUEUE SWiA'CHES: /flI. JE:~(JRT /COPiES:I /SPACING:I /LIMIT:IiO /~'ORNS:NO~MAL 8141 DATE 05-MAR-80 05-MAR-80 14:21:09 14:28:54 his VEF~5I~]N 15.nOt 1910J/20 SCHblJ/'4BLHGkP CU~qPUTING C~NI!E;R 10707~60003 LENG1 it: 132 B ~ TE;S REEL NAt~E: P.C.D.C. SERVICE NA~E: EDit RE[.:L CtJHTINUA".L'I(JI'~ NUfq~i~P: 01 PREVIOUS REEL NAIVE: CO~E, NI'S: bis ~i,JRt4AT CUSID~itER TAPE., DATk: 79/ 6/3(1 TAPE ~,EADER LENGI~H: 132 Bi 1:ES TAPE WANg: 55451 DATE: '/91 ~t30 SERV ].CE NAIVE: EDiT TAPE CUNTINUAllON NUlqBk~: O1 PREVIOIJS I'APE NAME: CLI~kNTS: IJNIOUk WELL 1DENTI.~'ICA~II(JN NUMBER iS 50-029-20]48 E (~ F FILl"; tiE:ADER bENGTH: 62 BYTES FI. LE NANE: EDIT R~ UR LE: MAXIMUFi PHYSICAL D NGTH 1024 PREV 1UU8 ~lbg FILE', CONM~zNTS BItSZ 8.5/~LOID LiGNUSUL~ATE/DENS IO.9/VLSC 17/PH lO.6/~'L LOSS 5.1/ RP1 1,76~7.]/RMP 1.34(aBg/RMC 2.35~57/RM(~BHT .B8~155/ CO.HPAN~ : A'IUA,NTIC RICHFiE;LD C WELl.., : NGI ~ 14 F: IEL[) : PRUDH(JE 6A~ RANGE TOWNSHIP : lin SECTION : 1 C [}[jN T.~ : NORTH SbtJPE STAT~ : AbASKA DENSIT~ : 800. E?~rRt' BLLICKS: 0 1 DATg~:! SPl::Cit',[CA'lilfJl~ bL(3CKS: NAI~'iE 'I'O(.~U ONl'r AP1 APl AP1 APl P-ILL SIZE SAi~ REP P~fJCYJSS ll~DICA~'I~O~8 1 OEPI E't 0 0 0 0 0 4 1 b8 2 SP D1L i,~V 7 1 0 0 0 4 1 68 3 CILD DIL MN~U ? 11 46 0 0 4 I 68 4 CILN D1L ~nU ? 11 44 0 0 4 1 68 5 CLLg DIL r~MHU 7 21 8 0 0 4 1 ~8 6 (;R ~HC GAPI 7 ~1 ~2 0 0 4 1 08 7 DT ~HC US/~ 7 52 32 O 0 4 I ~8 8 GR C~L GAP] 42 31 32 0 0 4 1 68 9 CALl CNL IN ~2 28 1 0 0 4 1 o8 10 DRHO PDC G/C3 42 44 0 0 0 4 I 6~ 11 NPHI CNL PU 42 68 3 o 0 4 I ~ 12 RH(}B ~DC G/C3 42 35 1 0 0 4 I ~8 1~ NRA:~ CNL C/C 42 42 1 0 0 4 1 ~ 14 NCNL CNL CPS 42 ]4 92 0 0 4 1 68 15 FCNL C~[, CPS 42 3~ 93 0 0 4 I 68 USER DEFINE:D EJ[I'IPUT ARP, A~ OU'tPUT SP AT 2 OtlTPgT C ILD A'I 3 UUTPUT CIL~ Al' 4 OUTPUT CLL8 A'I 5 OUTPgT G~ AT 6 OUTPUT DT A~ l OUTPUT GR A'I 8 OUTP[]T CALl A'I 9 OUTP[~T DRBO .AT 10 OUTPUT NP~i A% 11 OUTPUT RHOB AI 12 OUTPUT NRAT AI 13 OUTPUT NCNL AT 14 OUTPUT ~CNL Al 15 D~PI,h 95 30. 000 9500.000 9400.000 9300.000 9200. 000 9100.000 9000.000 8900.000 8800.000 8700.000 8600.000 M N L M O N I C 5P GR N C N L GR DHHO i, lC NL SP D F: H O N C N L SP GI~ NC N L SP GA DHH[,I NC NI., SP GR DRHO r~ C N L SP GH DRHO NC ~L 5P GR .N C N L 8P DRHO NCNb 8P 8P GR DHHU NCNb V A L U E -20.962 109.450 -999.000 -999.000 -25.747 107.26]~ -0.0~7 0.858 -77.127 51.355 -0.006 4~5.465 -79.897 2b.400 -0.025 634.062 -118.935 19.027 o0.030 684.684 -142.107 23.321 -0.011 769.626 -92.490 45.3~O -0.006 505.362 -95.261 '71.612 0.000 385.242 -77. 630 92. 840 -0.020 367. 224 -65.54i 180.995 -0.017 253.968 -62.267 103.373 -0.021 361.218 ~q i'~ E M O N 1 C CILD OT Nf)H i ~ CNL C DT NPH I ~CNL CIL, D DT ~PH I CILD DT NPHI ~CNb C ill) OT ]?CNL C iLl) NPH i ~CNL CILO DT NPHI FCNL ClLD DT NPHI ClLD DT NPH i PC NL CI, LD DT NPH1 C I DT NPHI PCNL VALUE 4~2.514 -999.250 -999.000 -999.000 4t2.514 -999.250 q5.180 0. 000 ~O.559 23.~00 196.482 21.281 86.188 12.380 394.680 5.1,52 77. 125 9.74{) 470.184 0.824 75.875 8.660 567.138 14 322 I 7. 720 256.1 13 24. 660 107.063 27.380 147.576 50.494 1,07.875 31.~80 1,26.126 1~7.494 119.813 42.880 69.927 !61.436 90.500 29.960 118.404 MN~MLJNIC CILM hHtjb CILM GR CiLM GR G~ C I L R H U ~i C I b M ILS GR H 0 ~ GR C ILt~ GR R H 0 B VAbOk 416.8~9 -999.000 -999.000 416.809 104.000 2.422 47.42,t 4~.600 2.180 lU.030 21.700 2.192 ~.792 18.200 2.548 3.837 21.100 2.339 12.942 38.400 2.155 24.43~1 ~6.200 2.158 ,4t.803 85.100 2.22t 165.959 17 O. 500 2.271 152. 757 90. 200 2.470 NNEMUNIC CLL8 CALl NRA'f Cbb8 CALl i"~RAT CLL8 CALl NRA:I' CLL8 CALX NRAT C LL 8 CALl NRAT Cbb8 CALl NRAT CLL8 CALl bRAT CLL8 CALl NRAT CbL8 C A b 1 N RAT Chh8 CALl NHAT C,bh8 CALl NRAT VALUE 304.789 -999.000 -999.000 304.789 3.300 0.002 3 '1.6 '70 8. 'l O0 2.330 7.810 1.~20 b.02b 8.750 1.412 0.092 8.800 1.320 9.290 8.950 2.052 29. 107 8.900 2.b08 25.586 9.300 2.92~ 99.083 10.050 3.010 79.433 10.500 2.844 DEPIN 8500.000 8~00,000 400,000 kr~it] t~ lC DRhO NCNb NCI~h 8P D R ~ 0 NCNL VAL UE -b0.252 137.56b -0.020 290.862 - ~ 7. 58. "'0. 247. -37. 58. "0. 247. 081 000 017 104 O00 017 104 CILD DT ~P~ i i~CNL CILD DT ~ChL CILD DT NPH I V A L tJt,'/ 140.o05 i06.250 83.226 185.~53 5~.250 34.220 69.92'1 185.t5~ 56.250 34.220 69.927 ?ll'l k,N (j N lC CILM VALUE 135.519 132.900 2.390 0.006 79.400 2.J90 0.00~ 79.4O0 2.~90 Cbb8 CALl Cbb8 CALl Iq R A 'r CLUB CALl NRAf VALU~ 83.17o 9.900 ~.432 515.229 lO.U00 3.380 515.229 10.000 3.380 RECO~.DS: 142 RECORD8: 9~6 0 ~ TE,S FILE 'f~AILEI~ LENGTbi: ~2 BYTES FiLE NAt+E: EDiT ,001 MAXIMUM PH'~:SICAL RECO~D LENGTH: ,NEXt[' ~'I. LE NAIVE: 1024 BYTE,S TAPE LENG1;H: 132 8~'I'ES TAPE Nh~4E: 55451 DATE: '/9/ 6/30 SERVICE NAME: EDiT TAPE C(jNTINUATION N[JMBERI Ol NEXT I'APE NA~iE: C(JM.MENT&S UNIOUE ~EL,L IDENTI~'ICATI(Jl~ NUMBER IS 50-029-20~8 30'dU N,- 79 IR:Il.:'27 18:11:58 PAC .It' iC CLIAS'I C{}i~,~I;)L!TiNG t:t:~NTt;'_~t;i 107Ob, 55~':t5;1 OAIE: 7q/ bt30 IF 1 L it i-,~ ii, A I.) E f.! bUSS 5.1 I ~ILA~'[ !C k. lCf4',r ll:,L,b' CU. , ,,UDti 1. BA¥ 0 i F~P CUD['] APt 0 7 1 7 ? '7 7 42 42.. ~2 o 1 1i 1.1 31 35 34 AP I 0 ~4 $ 3 2 3 2 0 1 1 q '.2 A P () 0 it 0 0 fi 0 0 SAint 1 1 1. 1 '1 1 1 1 1 1 1 1 1 1 68 ~8 ~8 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 o 0 i) ?_. t:' '1' H 9530. 000 g % 00.000 9 g(,O. 00() 9200.000 q ooO. 000 g"~00. 000 ,q 80 u. 000 ~ 7 {.~0. 000 a C N L SP q C N L S~~ t)[~ HtJ I"iC N b SP SP (,~ C N b $? DRHb SP D ~ H o NC NL 5P t) P, H L ~ SP N C N .b V A L U E -2u.9~2 -9q9.0 ~)() -25.7 '~ 7 1 O2. 551 -0.037 -77.12'7 53.72 3 '.' 0.006 920 0¢,~2 -ilt~.935 25.4.8e - 0.0 30 42.107 29.2~7 · -0.01 ] ?b9.62~ -92.49O 4u. (18e~ - 0. O 06 505..3 e 2 -95.26.1, "/1 0. O 0 0 3'65.242 - 17. ~30 89.957 -u.O2b lbo .954 '-O .017 263. -62.207 99.157 -o.021 Jt~l .21 8 CI DT , CiLL> OT FCF~b C i b D u T D T .,~ ~ P H i C 1. [., 1) UT aF'h 1 F CbtL C ILD DT F CFt b C I I., D lOT FC N t~ CiiJD 0 C I L D bT C IL, D N I:'" H I. ..-')99. 250 ,-9'49. 000 -9q9.00() 432.5i. 4 -999. 250 qb. 1 80 0.00 0 4b.559 23.60 t} ! ab. 21 .2~1 ! 2. 5.152 77. '125 9.'740 0.~.24 '75.875 8.e, 60 '~22 720 I I 3 24.6 t~ 0 ~ O? .0~3 ??. ~80 l...,/~ 7. % '7 6 5t~. 494 107. [q 75 Jl .680 126.1 2b 1 ~7. 494 119.813 42. R 80 69. g 27 qb. 50O 29. 960 GP Gl* C J t, ]. I., ~,.~ C 1 L M C I b~i 41 6. -999. - 9 ~ (9.000 41b.sb9 U 00 422 4 1. ,42 2.18u 21.. ? 00 2. 192 792 200 2,]48 3.~ ,t'7 21. lO0 2.339 12.942 38. q00 2.1.55 434 200 2. l. b8 7.86 3 ~5. l O0 2.221 le~5.959 2.2'71 152.757 90.2 O0 2.470 C C A L, t. C b L d C C Lb8 CAbi CbL8 (]ALi I: b 8 C~,Pi RAT C .bb 8 CALl C,~ R A T CbL8 C A b 1 N R h'.l.~ i.q P, A T C b L., 8 CALl i;,~ R A T CLL8 CALl C b b 8 C g..L, t N R A. T V AbU[~: 30~+. - 999.000 -999.000 304. 3.300 3'7 .~ tu U. lO0 2.330 800 .o20 150 4 l 2 0.092 8.800 1.320 9.z90 .950 O52 29. 107 ~ .900 2. 608 25.58e, 9.3O0 2.928 99. 083 10.050 3.olb 1 (). 500 2 '~"4 6P 8P VAbUt -~0o252 ].29.022 -o°02O 290.8~2 -37.081 59.52~ -0.u17 2~7.104 C 1 L, t9 0I' C: I [, [) L} :]'~ FC i40.605 10o.250 85.226 5~.25o ~.220 59.927 C 1 b ~4 VAD[]I~ ~5.51B 32.900 2.390 0.006 79.4.00 Cbb8 CAb1 Cbb~ CAt,,[ NRAT ~3.1/6 9.900 3.~32 515.229 10. 000 .l..:l:.:i\i(~'[~ C